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Home My WebLink About204-2137. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-213A Pull, Set Iso Sleeves Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-213 50-029-22993-01-00 12190 Conductor Surface Intermediate Production Slotted Liner 5220 80 2831 6846 5738 12183 20" 9-5/8" 7-5/8" 4-1/2" 5220 30 - 110 28 - 2859 24 - 6870 6446 - 12184 30 - 110 28 - 2829 24 - 5264 5198 - 5220 6760 520 3090 4790 7500 None 1530 5750 6890 8430 6868 - 12183 4-1/2" 12.6# L-80 26 - 5961 5264 - 5220 Structural 4-1/2" Baker Premier Packer 5844 4977 Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY, POLARIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028253 26 - 5038 N/A N/A 843 Well Not Online 4213 941 1375 1100 819 200 N/A 13b. Pools active after work:POLARIS OIL No SSSV Installed 5844, 4977 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:32 am, Sep 10, 2025 DSR-9/11/25J.Lau 11/4/25 RBDMS JSB 091525 ACTIVITY DATE SUMMARY 8/10/2025 ***WELL S/I ON ARRIVAL*** RAN 3.62" CENT & 10' x 3" PUMP BAILER & WORK FROM 5,450' SLM - 5,523' SLM (recovered 1.5 gal thick waxy paraffin) RAN 2.35" CENTRALIZER & 2" SAMPLE BAILER DOWN TO 6,120' SLM (recovered 1 cup paraffin) RAN 3" SAMPLE BAILER TO ISO SLEEVE AT 6,108' MD (recovered1/2 gal paraffin) RAN 3.25" GAUGE RING TO ISO SLEEVE AT 6,108' MD RAN 3.50" GAUGE RING TO ISO SLEEVE AT 6,108' MD ***CONTINUE ON 8/11/25 WSR*** 8/10/2025 T/I/O=1286/1252/358 Asit SL with B&F Pumped 72 bbls 180* dsl down tbg. ***job continued to 08-11-25*** 8/11/2025 ***CONTINUED FROM 8/10/25 WSR*** BRUSH & FLUSHED TUBING WITH 4-1/2" BLB, 3.62" GAUGE RING TO ISO SLEEVE @ 6,108' MD PULLED BAKER ISO SLEEVE FROM L2 LEM @ 6,108' MD ***WELL LEFT S/I ON DEPARTURE**** 8/11/2025 ***job continued from 08-10-25***Pumped an additional 48 bbls 180* DSL diwn tbg (120 total). Final T/I/O= 341/1277/398 8/19/2025 Assist SL SB to rig up 8/19/2025 ***WELL S/I ON ARRIVAL*** R/U POL-61 ***WSR CONT ON 8-20-25*** 8/20/2025 ***WSR CONT FROM 8-19-25*** BRUSH & FLUHED TUBING TO 6,150' SLM SET 4-1/2" BAKER ISO SLEEVE IN L2 @ 6,108' MD SET 4-1/2" BAKER ISO SLEEVE IN L3 @ 5,982' MD ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 8/20/2025 T/I/O= 524/1205/354 Assist SL With B&F Pumped 130 bbls 190* crude down tbg for SL. Final WHP's 0/1207/375 SL on well at departure Daily Report of Well Operations PBU S-213A Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-213A 204213 500292299301 4 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-213A RWO - Pull Iso Sleeve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-213 50-029-22993-01-00 12190 Conductor Surface Intermediate Production Liner 5220 80 2831 6846 5738 12183 20" 9-5/8" 7-5/8" 4-1/2" 5220 30 - 110 28 - 2859 26 - 6870 6446 - 12184 30 - 110 28 - 2829 26 - 5264 5198 - 5220 6760 520 3090 4790 7500 None 1530 5750 6890 8430 6541 - 12183 4-1/2" 12.6# L-80 22 - 5961 5215 - 5220 Structural 4-1/2" Baker Premier Packer 5844, 4977 5844 4977 Torin Roschinger Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, Polaris Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028253 22 - 5038 N/A N/A 1831 1120 3238 1 174 1133 950 1200 420 519 323-308 13b. Pools active after work:Polaris Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.20 06:18:17 -08'00' Torin Roschinger (4662) By Grace Christianson at 11:25 am, Jun 20, 2023 WCB 2-29-2024 DSR-6/21/23 RBDMS JSB 071423 ACTIVITY DATE SUMMARY 5/29/2023 T/I/O = SSV/1380/290. Temp = SI. Bleed IAP (pre RWO). No AL. IA FL @ 5510 sta #1, SO 144 bbls). Bled IAP to S-117 production from 1380 psi to 210 psi in 1 hr 20 min. OAP decreased 30 psi during bleed. IA FL unchanged. Did not monitor. Final WHPs SSV/210/260 Fullbore in control of well upon departure. 5/29/2023 T/I/O=1336/243 /264 (LOAD & KILL) Load & kill well prior to rig arrival. Pumped 50 bbls of crude to load the IA. *** job continued to 05-30-23*** 5/29/2023 T/I/O = MV/1380/290. Temp = SI. PPPOT-T **PASS**, PPPOT-IC **PASS** (pre RWO). Well is disconnected from the system, no flow line, well house. IA FL @ 5510' (sta #1, SO, 145 bbls). PPPOT-T: Stung into test port 700 psi, bled to 0 psi. Monitor for 10 min, no change in pressure. Function LDS, all move freely. Torqued to 450 ft/lbs. Pressured up to 5000 psi for 30 min test. Lost 200 psi in 1st 15 min, lost 0 psi in 2nd 15 min for a PASS. Bled void to 0 psi. PPPOT-IC: Stung into test void 300 psi, bled to 0 psi. Monitor for 10 min, no change in pressure. Pressured up to 3500 psi for 30 min test. Lost 100 psi in 1st 15 min, lost 0 psi in 2nd 15 min for a PASS. Bled void to 0 psi. SV, SSV, MV = C. IA, OA = OTG. 11:30 5/30/2023 *** job continued from 05-29-23*** Pumped 95 bbls 80* crude down IA (145 total), Pumped a 2 bbl 60/40 spear, 284 bbls Seawater w/ safelube down TBG. FP'd TBG with 38 bbls 60/40 Final WHP's Vac/Vac/330 Pad op notified 5/30/2023 Set 4" H CTS BPV, well support nipple down THA, clean void & ring groove, set CTS plug, cut & cap (1) 1/4" I wire, make up 4-1/2" TC-II test cross over to hanger lift threads 8-1/2 RH, test 500 psi./5 min., 4000 psi./ 10 min., good tests, bleed off test psi., upper lock down screws in=3-3/4", out=4-1/2", RDMO 6/2/2023 TB-1 RWO Job Scope: Fish ISO Sleeve, FCO As Needed MIRU TB-1. Spot base beam, kill skid, choke house, Koomey, pits, rig, and support equipment. R/U surface lines. Cleaned pits. R/U scaffolding and hooch. M/U 2-7/8" test joint. AOGCC Waived Witness (Kam ST John). Shell test w/2-7/8" TJ 250 psi low / 3000 psi high. Begin BOPE test w/2-7/8" test joint to 250 psi low / 3000 psi high. ........Job In Progress 6/3/2023 T/I/O = 1092/0/0. Pulled 4" "H" BPV through BOPs using 5' extension on lubricator for T-Bird. 6/3/2023 TB-1 RWO Job Scope: Fish ISO Sleeve, FCO As Needed Continue BOPE testing as per sundry 250 psi low / 3000 psi high. R/D test equipment. Pulled CTS insert. Nipple up shooting flange. Pulled BPV w/ lubricator. 1100 psi on tbg. Bullhead well w/ 300 bbls 1% KCL. FInal pressure 80 psi @ 5 bpm. Reduce rate to 2 bpm and open choke line to pits - no returns. Start min hole rate of 30 bbls/hour w/ charge pump from pit 1. Choke line open to pit 2 w/ alarm set for 1 bbl gain. ND shooting flange and set up floor, pipe racks, and pipe trailer to run work string. Run in DC's open ended and circ 5 bpm due to internal rust. Stand back collars. MU BHA #1 3" Hyd G Spear, 3-1/8" Circ sub, bumper, Oil Jar, 197' 3-1/8 DC's OAL 200'. TIH on 2-7/8" PH-6 WS. ...***Cont on WSR 6/4/23*** Daily Report of Well Operations PBU S-213A TB-1 RW O Job Scope: Fish ISO Sleeve, FCO As Needed Daily Report of Well Operations PBU S-213A 6/4/2023 RWO Completion, T/I/O = 0/0/0 Set TWCV # 432 with dry rod. Standby for rig crew to RDMO. 6/4/2023 TB-1 RWO Job Acope: Fish ISO Sleeve, FCO As Needed Continue RIH w/ BHA 1 & 2-7/8" work string, Get to Jt #188 of 192, connect kelly hose and wash down to fish. SD pump and engage fish @ 6101'. Pull 7K over and open jars. Fish moving uphole. Note 8K overpull when pulled though juction @ LEM #3. Contine TOH LD WS. Recovered fish. Stop hole fill and Set 'H" TWC. Start RD. ***Job Complete*** 6/4/2023 LRS Well Testing Unit 6, Begin WSR 6-4-23, IL Well S-213, SLBU, STBY for access, Cont WSR to 6-5-23 6/5/2023 LRS Well Testing Unit 6, Continue WSR from 6-4-23, IL Well S-213, SLBU, STBY for access, Cont WSR to 6-6-23 6/5/2023 RWO Completion T/I/O = TWC/0/0, PPPOT-T (PASS) Assist WS to remove BOPs, clean hanger neck, inspect TC-II lift threads, replace hanger neck seals, install THA and tree. Pressure test THA to 500 psi low, no loss, pressure test to 5000 psi, lost 200 psi first 15 mins, lost 0 psi second 15 mins, good tests, no pressure noted at SBMS monitor port during testing. Bleed all test pressure. WS pressure tested tree. RDMO 6/5/2023 T/I/O = TWC/0/0. Removed BOPs. Installed THA. PT by Vault Tech Sandau. Passed. Installed 4" Cameron Tree w/LEO facing 3 o'clock position, Torqued to spec. FWP = TWC/0/0 6/6/2023 RD 13" BOP and 10" DSA, Installed production tree, Torqued to specs, PT'd against TWC 350-5000 PSI (Pass). Pulled 4" H TWC. RDMO 6/6/2023 LRS Well Testing Unit 6, Continue WSR from 6-5-23, IL Well S-213, SLBU, STBY for access, Cont WSR to 6-7-23 6/7/2023 LRS Well Testing Unit 6, Continue WSR from 6-6-23, IL Well S-213, SLBU, STBY for access, Move In, RU, PT, SB, Cont WSR to 6-8-23 6/8/2023 LRS Well Testing Unit 6, Continue WSR from 6-7-23, IL Well S-213, SLBU, End SB, POP Well. Cont WSR to 6-9-23 6/9/2023 LRS Well Testing Unit 6, Continue WSR from 6-8-23, IL Well S-213, SLBU, End SB, POP Well. Cont WSR to 6-10-23 6/10/2023 LRS Well Testing Unit 6, Continue WSR from 6-9-23, IL Well S-213, SLBU, End SB, POP Well. Cont WSR to 6-11-23 6/11/2023 LRS Well Testing Unit 6, Continue WSR from 6-10-23, IL Well S-213, SLBU, End SB, POP Well. Begin 12hr WT, Cont WSR to 6-12-23 6/12/2023 LRS Well Testing Unit 6, Continue WSR from 6-11-23, IL Well S-213, SLBU, Complete 12hr WT, Perform 2 HR WT per pad OP, Cont WSR to 6-13-23, 6/13/2023 LRS Well Testing Unit 6, Continue WSR from 6-12-23, IL Well S-213, SLBU, Complete 12hr WT, Perform 2 HR WT per pad OP, Cont WSR to 6-14-23, 6/14/2023 LRS Well Testing Unit 6, Continue WSR from 6-13-23, IL Well S-213, SLBU, Perform Multiple 2 HR WT while increasing GLR, Cont SLBU opening IL CK, Cont WSR to 6- 15-23, 6/15/2023 LRS Well Testing Unit 6, Continue WSR from 6-14-23, IL Well S-213, SLBU, Perform Multiple 2 HR WT while increasing GLR, Cont SLBU opening IL CK, Cont WSR to 6- 16-23, 6/16/2023 LRS Well Testing Unit 6, Continue WSR from 6-15-23, IL Well S-213, SLBU, Perform Multiple 2 HR WT while increasing GLR, Cont SLBU opening IL CK, Cont WSR to 6- 17-23, Continue RIH w/ BHA 1 & 2-7/8" work string, Get to Jt #188 of 192, connect kelly g y hose and wash down to fish. SD pump and engage fish @ 6101'. Pull 7K over and gg @ open jars. Fish moving uphole. Note 8K overpull when pulled though juction @ LEMjg #3. Contine TOH LD W S. Recovered fish. Daily Report of Well Operations PBU S-213A 6/17/2023 LRS Well Testing Unit 6, Continue WSR from 6-16-23, IL Well S-213, SLBU, Perform Multiple 2 HR WT while increasing GLR, Cont SLBU opening IL CK, Cont WSR to 6- 18-23, 6/18/2023 LRS Well Testing Unit 6, Continue WSR from 6-17-23, IL Well S-213, SLBU, Perform Multiple 2 HR WT while increasing GLR, Cont SLBU opening IL CK, Cont WSR to 6- 19-23, 6/18/2023 LRS 72 Assist Well Test (PROFILE MODIFICATION). Pumped 35 bbls of 180*F diesel to flush surface lines. 6/19/2023 LRS Well Testing Unit 6, Continue WSR from 6-18-23, IL Well S-213, SLBU, Perform Multiple 2 HR WT while increasing GLR, Cont SLBU opening IL CK, RDMO. End WSR to 6-19-23, 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-213A RWO - pull & reset isolation sleeve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-213 50-029-22993-01-00 N/A ADL 0028253 12190 Conductor Surface Intermediate Production Liner 5220 80 2831 6846 12183 20" 9-5/8" 7-5/8" 5220 30 - 110 28 - 2859 24 - 6870 859 30 - 110 28 - 2829 24 - 5264 6760 520 3090 4790 none 1530 5750 6890 6868 - 12183 4-1/2" 12.6# L-80 26 - 59615264 - 5220 Structural 4-1/2" Baker Premier No SSSV Installed 5844 / 4977 No SSSV Installed Date: Torin Roschinger Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY 6/8/2023 Current Pools: POLARIS OIL Proposed Pools: POLARIS OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:00 pm, May 25, 2023 323-308 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.25 13:24:05 -08'00' Torin Roschinger (4662) 859 10-404 SFD 5/30/2023MGR31MAY23 DSR-5/25/23 BOPE test to 3000 psi. Annular to 2500 psi. GCW 05/31/23 05/31/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.05.31 10:23:03 -08'00' RBDMS JSB 060123 TB#1 Fish Well: S-213a PTD: 204-213 Well Name:S-213a API Number:50-029-22993-01-00 Current Status:Operable Multilat Prod Estimated Start Date:6/8/2023 Sundry #?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker First Call Engineer:Brodie Wages (713) 380-9836 (M) Second Call Engineer:Josh Stephens (907) 779-1200 (M) AFE #: Current Bottom Hole Pressure:1364 psi @ 5046’ TVD 5.2 PPGE | (S-215 DHPG on 5/23/23) Max. Anticipated Surface Pressure:859 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:220 psi (Taken on 11/6/2022) Min ID:2.57” IsoSleeve @ 6102’ MD Max Angle:98 Deg @ 7397’ MD Tubing spool:11” 5,000 psi FMC MITs: MIT-IA: 3500 psi on 7/4/2001 Passing TIFL 2/6/2006 Brief Well Summary: S-213 is gas lifted via an MBE from S-217 in the Oba. The ported isolation sleeve installed over the Oba lateral was helping to reduce slugging which was helping to reduce solids influx seems to have helped the well sand off. Prior to sending coil out for a FCO, we need to pull the isolation sleeve. Welltec’s stroker tool was able to unseat the sleeve and move it uphole ~14’ to where the lower sealstack of the sleeve is in the upper sealbore of the LEM at which point the tool or the rope socket failed. Due to the required anchor positions, we are unable to continue to use the stroker duo to the OA LEM window above us. WELL IS MECHANICALLY SOUND WITH MINIMAL FISH LEFT IN HOLE Objective: Pull iso sleeve Notes Regarding Wellbore Condition 2/23/2005: slickline pull B&R post sidetrack, install initial GL design Initial well tests: 1750 bopd 12/20/2005: B&F, w/ diesel/xylene, made it to deviation @ 6190’ with no issues. 12/23/2005: iCoil- x 2.25” nozzle hung up and entered OBc several times, eventually made it to OBd, locked up at 10,670’. Wash all juncitons with diesel/xylene. x PDS logging run, lost 5 arms off centralizer, 1 arm of other centralizer, no spinner data x BOT Venturi and 3.65” gauge ring, unable to get past SS @ 5796’, recover nothing, no marks on tool x 2.13” motor and venturi, work down to 5955’ (LEM#3) x MU Venturi and 3.65” gage, make it to 6380’, hung up, mottom of LEM #2, jar off and work free, POH. Metal chips in shoe, nothing in venturi, marks on inside indicating pushing down centralizer arms. x RIH with same BHA, work and rotate from 6350’ to 6760’, POH from there, recovered two metal stringers and scale like flakes. x RIH w/ 3.67” diverter for LEM#1, jar thru LEM #3, set in 1, POH, cut coil. The ported isolation sleeve installed over the Oba lateral TB#1 Fish Well: S-213a PTD: 204-213 x Water handling problems at GC2, RIH w/ 2.25” nozzle, tag up @ 6485’, ~2 joints into slotted liner of OBc, wash through to 7000’. x Oil sampler tool in OBc at 6700’, second sample failed. x 2nd sampler run, collect at 8500’ x 2.25” OD special side jetter, make it to 10,426’ bridges around 9000’ x MU and RIH w/ 2.2” JSN, all day in OBc lateral x Re-start OBc cleanout, some tags around 9350’, cleanout complete x Re-head and MU 4” GS to pull diverter @ 6400’, latch and POOH. x Set isolation sleeve in LEM #2 @ 6110’ x RDMO 6/9/2006: coil venturi run, tag to of isolation sleeve, MU and RIH with 4” GS, latch and POH 8/31/2007: Eline - SBHPS 7/27/2008: Slickline, B&F w/ 3.8” g ring pre coil, tag @ 5777’ 8/7/2008: x 3.65” venturi w/ cutlip guide shoe w/ motor to 6550’ x 3.5” spiral centalizers and downhole samplers, set down in L1 at 6418’, unable to pas through, PUH to 6350’ and allow sampler to pull samples, also caught sample at wellhead. x 3” JSN to 6200 – 5950’ w/ diesel/xylene x MU Dual sampler with logging tools, run to 6550, confirm oil sample taken from OBd mainbore. x RIH w/ hip tripper and orifice sleeve w/ one ¼” port, unable to set (fines in fishing neck area) x Reset G and Isosleeve, set at 6115’, RDMO. 10/26/2009: Eline – Gas lift survey 2/11/2011: Coil – drift w/ JSN to 6084’, pull iso sleeve w/ G-spear, 1 jar lick, RDMO 2/10/2013: Coil – 3” JSN w/ 3.5” spiral centralizer, pump diesel/xylene from 6200’ – 5950’, set ported iso sleeve over L2, hip trip in, 5k to shear out, reset, 3k pull check. 7/21/2016: Slickline – drift, pull isosleeve in several attempts 8/4/2017: slickline drift, bailer came back with 1 gal brown goo 9/25/2017: Coil – x FCO BHA w/ double knuckle, straight bar, 2.375” GR/CCL and 2.75” JSN. Get well flowing with LRS, tagged hydrates at 737’, worked down with KCl then 50/50 to 2200’, get well flowing then attempt to drift, unable to get past 6002’ (L3 LEM) due to mechanical obstruction. x BHA#2 FCO BHA. Able to drift down to 6700’ dry. Pump gel sweep and chase OOH. Had overpulls from potential fish at 6412’ and at 6211’. Log confirmed we were in motherbore. o FCO BHA: 2.25" CTC x 1.37' len, 2.13" DFCV x 1.38', 2.13" knuckle x 0.84', 2.13" knuckle x 0.84' len, 2.13" straight bar x 4.76' len, 2.13" straight bar x 4.65' len, 2.13" TJ disco w/ 5/8" disco seat x 1.57' len, 2.13" circ sub w/ 1/2" ball seat x 1.01' len, 2.375" HES GR/CCL carrier x 9.85' len, 2.0" X-O x 0.27' len, 2.15" X-O x 0.33' len, 2.75" JSN x 0.58' len. (OAL 27.45') x 4” GS pulled isosleeve no issues, reset in same run, RDMO 12/6/2018: Slickline – drift, pull iso sleeve, reset iso sleeve with some effort 10/12/2019: slickline – drift with 2.25” cent and 1.5” bailer to deviation 11/4/2022: Slickline – drift with braided line, unable to get past 5952’, recovered ~3 cups fill w/ 3” sample bailer, 117’ of fill. 11/16/22: Coil with N2/Testers assist – FCO to top of iso sleeve, jar on sleeve 50+ times, ended up jarring out of fishing neck, perform FCO through Iso-sleeve. Turned well over to Ops. Slickline planted a specialized spear and Eline with Welltec stroker was able to pull the sleeve uphole 14’. When the bottom seal stack on the sleeve made it to the upper sealbore of L2 LEM we had a 65k# overpull (see screenshot below) and the wire shorted in the ropesocket. Slickline followed up and retrieved the welltec tools and spear. The ISO sleeve is still there. TB#1 Fish Well: S-213a PTD: 204-213 3/24/2023: latest flowing data: 2000 bopd, 200 bwpd, 3.5 mmscfd formation gas with 1.2 mmscfd GL. 2.0% solids while choked back at 82 beans on a 176 choke. SOLIDS % IS WHY WE ARE HERE. Volumes: Feature Depth, feet Volume, bbls Vol b/w feature, bbls Tubing tail 5961 90.6 Top of LEM #3 5982 90.9 0.3 Top of LEM # 2 6111 92.9 2 Top of Lem #1 6393 97.2 4.3 Motherbore Liner hanger 6457 98.1 0.9 IA Volume 5510 229 Procedure Slickline -COMPLETE 1. MIRU and pressure test 2. Drift and tag fish a. Be careful going through L3 LEM b. If unable to plant due to fill, plan to install spear after coil performs FCO 3. Install bait spear a. Use same one as previously installed on 2/21/23 i. 3.65” “old style releasable spear in iso sleeve” Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. The BH gauge in S-215 in the OA can be used to monitor BHP. There is an MBE in the OA from S-215 to S-213, the OA is dummied off in S-215 so the gauge in S-215 it is actively monitoring on S-213 BHP live. 1 week prior to RWO, shut in the following wells: S-217. 4. Spot Pump Truck, RU and PT. 5. Load IA with dead crude or diesel a. 229 bbls 6. Pump ~150 bbls down tubing to confirm 2% KCl to be used as KWF a. Monitor S-215 OA DHG to verify still active and recording S-213 BHP 7. Freeze protect tubing with 40 bbls diesel or dead crude 8. RDMO pumpers 9. RD well house and flowlines. Clear and level area around well. 10. Set BPV w/insert (TWC) and test. ND Tree and THA. 11. NU BOPE configured top down: Annular, 2-7/8” x 5” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Thunderbird #1 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/1% KCl as needed. TB#1 Fish Well: S-213a PTD: 204-213 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird #1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 2-7/8”test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU hydraulic 3-1/2” GS spear to latch into the releasable spear. a. 6000’ or 7.9# workstring weighs 47k# b. Max tensile rating of workstring is 248k# c. Discuss with OE final fishing BHA, we want to do straight pulls to start d. See Welltec stroker pull sheet below and AWGRs reports on 2/21/2023, it took 102k# to unseat the iso sleeve from the LEM sealbore/snaplatch. The tool shorted out at 65k#. Expect the initial pull to get the lower seal stack through the upper seal bore to be at least 65k#. e. It is odd that the sleeve was still taking 30-50k pulls between sealstacks as it traveled through the LEM. There may be a chunk of metal or a GLV part wedged between the OD of the sleeve and the ID of the completion equipment. 6. RIH, latch into fish and POH a. Start with straight pulls/pushes b. Work into gentle jarring action followed by bigger and bigger hits c. Take accurate measurements of fishing assemblies, ensure town and field have most recent and up to date specs on equipment for every run. d. Monitor S-215 while POH, we don’t want to swab in a gas bubble. Ask OE for help if needed 7. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 8. RDMO Thunderbird WO Rig and ancillary equipment. Move to next well location. 9. RU crane. ND BOPE. 10. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 11. Pull BPV with TWC insert. 12. Replace wellhouse and gauge(s) if removed. Testers 1. POP well via SLBU a. Open the choke to minimum choke position that allows the well to flow in a hydrate-free region, roughly 45 beans. Start GL at 0.5 MMSCFD and maintain this setting until the IA pressure drops below the lowest bellows opening pressure of 1500 psi. b. After IA pressure drop is observed, increase GL rate to 1 – 1.5 MMSCFD, adjust GL rate as necessary to reduce slugging. Maintain minimum choke setting and GL rate for 6 hours to allow the well to warm up. c. Consider adjusting the choke if the WHT is <50F and/or WHP is >500 psi for a prolonged period. TB#1 Fish Well: S-213a PTD: 204-213 d. Expect WHP to initially drop when opening the choke until GL has time to build pressure and KO well. e. If well is setup with continuous AF / EB injection at the wellhead, add as necessary to help reduce slugging until well stabilizes out. f. If well is setup for continuous methanol injection, add methanol into the GL stream as necessary until well is warm and stable. g. After the 6 hour hold period, open choke 2 steps h. Adjust GL as necessary to achieve stable flow and limited slugging. Target 1500 TGLR. i. Hold at this choke setting until 200 bbls of fluid have been produced (two bottoms up) or about 2 hours. 2. Continue to open choke 2 steps every 2 hours while monitoring WHT and BH pressure 3. Discuss speeding up bean-up program with OE as needed. Coil – IF SOLIDS DO NOT CLEAN UP WITH TESTERS or if rate is below expectations Likely to be updated to include an OA FCO 1. MIRU, pressure test 2. MU and RIH with FCO BHA 3. MU FCO BHA a. Suggest BHA #2 from 2017 RU, highlighted BOLD above 4. FCO motherbore/OBd to as deep as possible a. Review 2005 iCoil intervention, debris left in well 5. Shut well in 6. MU BHA to re-run Iso sleeve with ¼” port over to regulate flow from L2 7. Install iso sleeve in LEM#2 @ ~6115’ 8. POH, obtain stabilized well rates with testers, discuss need to continue Coil work with OE 9. RDMO Testers 4. POP well via SLBU Coil – TB#1 Fish Well: S-213a PTD: 204-213 Current WBD: TB#1 Fish Well: S-213a PTD: 204-213 TB#1 Fish Well: S-213a PTD: 204-213 X/O Spool to 11” 5k# TB#1 Fish Well: S-213a PTD: 204-213 Isolation Sleeve installed in LEM2: TB#1 Fish Well: S-213a PTD: 204-213 TB#1 Fish Well: S-213a PTD: 204-213 S-213a Cross Section GR10 110Perm.2 2000-4950-5000-5050-5100-5150-5200-5250OAOBaOBbOBcOBdOBeS-213AOAOBaOBbOBcOBdOBeTVDSSS-213S-213AS-213AL1-01Permeability generally<100md.Permeability generally>100md.GasTD - 12,054‘ MDLength - 6057’Total Footage Drilled: 31,564' MDTotal High-Angle Footage: 27,540' MDTotal Slotted Liner Run: 24,448' MDTotal Net Pay: 16,755' MDTD - 12,100‘ MDLength - 5980’TD - 12,043‘ MDLength - 4442’TD - 12,160‘ MDLength - 5751’TD - 12,190‘ MDLength - 5310’ TB#1 Fish Well: S-213a PTD: 204-213 Welltec Stroke tensions, note 65k# overpull at final pull before tool failure: TB#1 Fish Well: S-213a PTD: 204-213 EXAMPLE LEM (this sketch is from L-203) · . Image Project Well History File Cover Page XHVZE This page identifies those ítems that were not scanned during the initial production scanníng phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 Y:- - ~ j 3 Well History File Identifier Organizing (done) o Two-side~d 1111111111111111111 o Rescan Needed 111111111111111I111 R~CAN ~ Color Items: o Greyscale Items: DIGITAL DATA ~skettes, No. , o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: .f o Other:: BY: G:;) Date: l.f, ¡ d-, 07 Isl vnp BY: ~ Date '+/I'J-I D 7 (; x 30 = J ß'O Date If!Ia-/07 11111111111111 rrlll Project Proofing Scanning Preparation BY: ~ rhP + +-=j = TOTAL PAGES J ß3 (Count does not i~~;ude cover sheet) m p Isl Production Scanning Stage 1 Page Count from Scanned File: 1 15 LJ- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES Date Lt 11:;1.1 0 7 If NO in stage 1 page(s) discrepancies were found: 11111111111111" III Stage 1 YES NO 151 rn p NO BY: C Maria "} BY: Maria Date: 151 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111I1111111 BY: Maria Date: Isl Comments about this file: Quality Checked 11111111111I II11II1 10/6/2005 Well History File Cover Page. doc STATE OF ALASKA MAR 0 K) 2013 AKA OIL AND GAS CONSERVATION COMAPION REPORT OF SUNDRY WELL OPERATIONS A0G ;+' 1. Operations Abandon Lf Repair Well Ll Plug Perforations Lf Perforate Lf Other U P orted 'so Sleeve Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name. BP Exploration (Alaska), Inc Development 0 Exploratory ❑ - 204 -213 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029- 22993 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ' ADL0028253 PLRS S -213A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): - To Be Submitted PRUDHOE BAY, POLARIS OIL 11. Present Well Condition Summary: Total Depth measured 12190 feet Plugs measured None feet true vertical 5220.45 feet Junk measured 6760 feet Effective Depth measured 12183 feet Packer measured See Attachment feet true vertical 5220.24 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H -40 30 - 110 30 - 110 1530 520 Surface 2831 9 -5/8" 40# L -80 28 - 2859 28 - 2828.94 5750 3090 Intermediate None None None None None None Production 6846 7 -5/8" 29.7# L -80 24 - 6870 24 - 5263.71 6890 4790 Liner None None None None None None Perforation depth Measured depth 6868 - 12183 feet ;(°� True Vertical depth 5263.52 - 5220.24 feet � m APR 19 2033 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 26 - 5961 26 - 5038.4 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 579 512 367 987 350 Subsequent to operation: 734 705 411 983 233 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil r El Gas ❑ WDSPLLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summ BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signature //�1/0145/�� .,, Phone 564 -4035 Date 3/5/2013 RSDMS MAR 0 6 2013 IN 4- /t 7-1 t 3 Form 10-404 Revised 10/2012 / " �� Submit Original Only • • Daily Report of Well Operations ADL0028253 . . . �n _ "� SUMMARY 10 •U 1 •1 • -- prole - mo. B &F FROM SURFACE TO 5930' SLM W/ 4 -1/2" BLB & 3.625" G.RING WHILE LRS PUMPS 90 BBLS OF HOT DIESEL. 1/28/2013 ** *WELL LEFT S /I, PAD OP NOTIFIED * ** ** *WELL FLOWING ONARR1VAL ** *(profile -mod) B &F FROM SURFACE TO 5930' SLM W/ 4 -1/2" BRUSH, 3.625" G.RING & 90 BBLS OF HOT DIESEL. 1/28/2013 ** *WELL LEFT S /I, PAD OP NOTIFIED * ** T /I /O= 522/870/249 Assist S/L w /Brush and Flush Pumped 10 neat meth down flowline to freeze protect. Pumped 5 bbls Neat Methanol followed by 90 bbls 180* DSL and capped with 5 bbls Neat Methanol down tubing to assist S /L. SSL in controle of well notified pad op upon departure. FWHP = 350/900/300 SV/W /SSV /M = SSL IA/OA = OTG 1/28/2013 Cost Place Holder for purchase of a type 1 LEM converted to a type 2 LEM isolation 2/5/2013 sleeve with one 1/4" orifice. C rU #9 1.75" coil Job objective: Diesel/ Xylene Wash L2 junction, Set Ported Isolation Sleeve with 16/64" orifice in L2 MIRU, Make up BOT BHA #1: 3.5" spiral centralizer, 3" BDJSN. / Pump 20 bbls of diesel xylene and reciprocate from 6200' to 5950' and chase out of hole pumping hot diesel. 2/10/2013 «Job Continued on 02- 11 -13» T /1 /0 = 240/1020/220 Temp = S71 Assist CTU. Pumped 38 bbls 100* Diesel followed by 29 bbls 140* Diesel followed by 21 bbls 100* Diesel Xylene mix and 205 bbls 140* Diesel 2/10/2013 down CTU to assist. ** *WSR continued to 2- 11 -13 * ** CTU #9 1.75" coil Job objective: Diesel7Xylene Wash L2 junction, Set Ported Isolation Sleeve with 16/64" orifice in L2 / «< Continue WSR from 2/10/13 »> RIH with baker Si- Di hipp tripper and # 2 / 3.50" isolation sleeve. Sleeve latched up at 6122', CTM picked up and unlatch it took 5 k over up wt set back down and relatch pick up 3 k over up weight set down and hip tripped down no more movement down and pumped off POOH. 2/11/2013 «< Job complete »> ** *WSR continued from 2- 10 -13 * ** Assist Coil & Heat CH2MHILL Diesel Transport. FWHP = 470/1062/213 Coil in controle of well notified pad op upon departure. 2/11/2013 SV/W /SSV /M /IA/OA = CTU FLUIDS PUMPED BBLS 488 DIESEL 20 METH 24 XYLENE 62 60/40 METH 594 TOTAL Casing / Tubing Attachment 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 30 - 110 30 - 110 1530 520 PRODUCTION 6846 7 -5/8" 29.7# L -80 24 - 6870 24 - 5263.71 6890 4790 S- 213AL3 SLOTTED LINE 5139 4 -1/2" 12.6# L -80 5945 - 11084 5030.4 - 5210.34 8430 7500 S- 213AL2 SLOTTED LINE 5610 4 -1/2" 12.6# L -80 6055 - 11665 5082.4 - 5219.75 8430 7500 S- 213AL1 SLOTTED LINE 5631 4 -1/2" 12.6# L -80 6335 - 11966 5175.35 - 5222.24 8430 7500 1 S- 213AL1 -01 SLOTTED LINE 5738 4 -1/2" 12.6# L -80 6446 - 12184 5198.2 - 5220.27 8430 7500 S -213A SLOTTED LINE 4583 4 -1/2" 12.6# L -80 7577 - 12160 5219.3 - 5219.75 8430 7500 • SURFACE 2831 9 -5/8" 40# L -80 28 - 2859 28 - 2828.94 5750 3090 TUBING 5935 4 -1/2" 12.6# L -80 26 - 5961 26 - 5038.4 8430 7500 • 1 1 • • Packers and SSV's Attachment ADL0028253 SW Name Type MD TVD Depscription S -213A PACKER 5844 4915.16 4 -1/2" Baker Premier Packer S -213A PACKER 5956 4974.09 5 -1/2" BAKER ZXP PACKER S -213A PACKER 6066 5025.33 5 -1/2" BAKER ZXP PACKER S -213A PACKER 6346 5116.07 5 -1/2" BAKER ZXP PACKER S -213A PACKER 6457 5138.41 5 -1/2" BAKER ZXP PACKER TRH= 4-1/16" txw • S -213A NOTES: WELL ANGLE> 70° @ 6175'. WELLHEAD= 11' MC (L1, L1 -01, L2, L3) ORIGINAL WELLBORE NOT SHOWN BELOW 7" ACTUATOR= L® CSG CUT @ 2912' (11/22/04). * * *DOWNHOLE FOAL KB. ELEV = 61.82' I GAUGES INOP AS OF 08122/06 * ** - KOP= 2450' f 996' H9 -5/8" TAM PORT COLLAR 1 Mix Angle = 98° @ 7397' 20 "Conn -I 110' _ " Mum MD - 6009' 1 2255 �- , 4 -112 1-ES X nl D - 3.813 DatumTVD= 5000' SS IL GAS LIFT MANDRELS ST MD 1 7VD j DEV 1 TYPE VLV I LATCH I PORT DATE 19 -5/8" CSG, 40#, L -80 BTC, D = 8.835" -1 2859' 4 2739 2720 23 KGB2 DONE BK 16 02/24/05 3 4238 3852 44 KGB2 DONE BK 16 02/24/05 Minimum ID = 2.57" (p7 6122' CTM 2 5357 4657 44 KGB2 DMY BK 0 02/24/05 PORTED ISOLATION SLEEVE 1 5510 4766 46 KGB2 SO BK 24 02/24/05 FHOB.IX DISCHARGE H 5785' 0 I I 5796' H 4-1 /2" BKR CND SLD SLV, D = 3.813" 1 FRESS GAUGE„ D = 3.85" PFIOE>`IX NYTAKE --1 5820' 1 k7.9 5844' -I 7 -518 X 4-1/2" BKR PRE,I FKR, 0 = 3.875" PRESSURE GAUGE D = 3.85" r -- -J 5913' H4 -1/2" IBS X NP,D = 3.813" I 17 -5/8" RA TAG H 5940' r "-- I 5934' H4 -1/2" I-ES X WO = 3.813" 1 17 -5/8" X 5 -1/2" BKR ZXP LTP , D = 4.950" H 5956' 5961' H4 -1/2" NtLESHOE, D = 3.958" 4 -1/2" TBG, 12.6#,L -80 BT, 5961' 5964' 1 1 5-1 /2" X 4-1/2" XO, O = 3.958" 0152 bpf, ID= 3.958" L ■ ® �� - - - - L3 (OA) LEM WINDOW 61° L3 (OA) 5986' - 5997' BAKER HOOK HANGER --I 5982' ® ® OPENING WIDTH = 3.33" w / L3 SEALING LEM, D = 3.688" 17- 518 "RA TAG H 6062' k 4 6074' --I 6' BKR SEAL BORE EXTENSION, D = 4.750" I 17 -5/8" 5-1/2" BKR ZXP LW, D = 4.950 1-1 6066' AP 6093' - 15 -1/2" X 4-1/2" XO, D = 3.958" 1 mi l - 'LEM #3 LOWER SEAL ASSY, D= 3.958" -1 6081' '" '� L2 (OBa) LEM WINDOW 67° BAKER HOOK HANGER -1 6111' 1 .' L2 (OBa) 6108' - 6119' will SEA LNG LEM, D = 3.686' ..::111..... OPENING WIDTH = 3.33" ` f II ♦ , S� FSH NOTE E� 6760' I TI OBb LATERAL 11 -01 4-1/2" PORT® ISO SLV, 16/64" FORT 6122' CTM IS HIND OBc SLOTTED LNR 111 ID= 2.57 {02!11/13) J ` @ (NOT ACCeSS18l E) ��7�� -5/g` X 5-1/2' BKR ZXP LIP ' -- - 1 6346' w / SEAL BORE EXT, D = 4.750" 6' ALUMNIMA 7577' 17 -5/8" RA TAG - 6347' BILLET LNR TOP 7 � � I ft) I5 -i/2" X 4 -1/2" XO, D= 3.958' H 6374' ' SEE FISH NOTE @, 6760' I ' LEM #2 LOWER SEAL ASSY , D = 3.958" . -1 6380' . • •• _ _ ® ® c�- - - • , ' - - L1 (OBc) LEN WINDOW 78° BAKER HOOK HANGER -1 6393' 1 L1 -01 (OBc) 41611 6397' - 6408' w / L1 SEALING LEN, D = 3.688" • - -- - - - -- OPENING WIDTH = 3.33" 1 LEM #1 LOWER SEAL ASSY, D = 3.958' -1 6490' I ■ H 11' LNR T�3ACK SLV, D = 5.750" 1 6457' H7-5/8" X 5-1/2" BKR ZXPw / HMC UsEt HGR, D = 4.870* 1 7 -5/8" LNR, 29.7 #, L -80 STL -FJ, -I 6870' 6474' IH6.25" SEAL BORE EXTENSION, D = 4.750" 1 .0459 bpf, I) = 6.875' 6493' - 1- -15 -1/2" X 4-1/2" XO, D = 3.958" 1 P92FORATION SUMMARY 67 03' I- I7 -5/8" RA TAG' REF LOG I I ANGLE AT TOP PERT: i i 6760' I- ASH- FIVE FOS CENTRALIZER ARMS LOST @ L9ul #2. Note: Refer to Ftoduction DB for historical perf data :S -213A DEBRIS PUS D MALBORE, BUT POSSBLE FISH SIZE] SPF 1 M792VAL I Opn/Sgz I DATE I 0Bd I Lt & L2 (12/26/05) SEE PAGE 2 FOR LATERAL INFORMATION t 1 1 I I DATE REV BY CONVENTS DATE REV BY CONVENTS POLARIS UNIT 01/10/01 N9ES ORIGINAL COMPLETION 08/24/09 TW/PJC F DATE CTTON WELL: S 213A 02/03/05 1)16 SIDETRACK "5 -213A" 03/04/13 JRP/JND SET PDRTT) LSO SLV ANAL (02/11/13) I2MT No: 2042130 (140) (150) (160) 170) 12/03/05 JPK/Tlt GLV C/O (0212d/05) API No: 50- 029 - 22993 -01 (60) (61) (62) (63) JGM�TLH BKR ISO SLV SET SEC 35, T12N, R12E, 934' F & 780' FWL 02/18/08 TW /PJC DRLG DRAFT OOFEEC IONS 08/24/09 TW/PJC FB2F DATE CORRECTIONS BP Exploration (Alaska) • S -213A (L1, L1-01, L2, L3) 1 CUT ORIGINAL r CASING ON 05/02/03 @ 2912' OH SIDETRACK FOR S-213A@ 2856' 1 6036' - 11804' 6 -3/4" L3 (OA) 4-1/2" LNR, L-80 BT -M, .0152 bpf, D = 3.958" PERFORATION SUMMARY 4 REF LOG: ■ ® f ea ANGLE AT TOP PERF: 4 SWELL PKR's @ 6103' & 6512' Note: Refer to Production DB for historical perf data SIZE SPF ZONE MERVAL Opn/Sqz DATE an 4-1/2 SLTD OA 6541 - 11803 0 01/31/05 JOA FBTD 11803' 4-12" SLID OBa 6267 -11622 0 01/20/05 6111' - 11665' 6 -3/4" 12 (OBa) 4-112* SLID OBb 7588 - 7787 0 12/21/04 4-1/2" LW, 1-80 BT -M, .0152 bpf, D = 3.958" 4-1/2" SLID OBb 7996 - 12117 0 12/21/04 4-1/2 SLID OBc 6459 - 6792 0 01/02/05 4-12" SLID OBc 7483 - 11923 0 01/02/05 4-112" SLID OBd 6868 - 12183 0 12/13/04 = IOBa PBTD H 11664' - 7588' - 12160' 6-3/4'11 (OBb) 4-1/2" LM2, L -80 BT-M, .0152 bpf, D = 3.958" 4 12 "SWELL PKR 7890' sa C 4 -12 - SWELL PKRs a 6805' & 7458' Qa as 10 ID H 5c 11 11965' 6393' - 11966' 6 -3/4" L1 -01 (OBc) 4-1/2" LM2,1 -80 BT -M, .0152 bpf, D = 3.958" 1 I I I load PBTD I S -213P OBd I 6446' - 12184' 6 -3/4" OBd LATERAL I 4-1/2" SLOTTED LM2, 12.6#, L -80 BT 12184' 1 1 .0152 bpf, D = 3.958" DATE REV BY ODMYUJTS DATE REV BY CONN:NTS POLARIS UNIT 01/10/01 N9ES ORIGINAL COMPLETION 08/24/09 TW/PJC P6RF DATE CORRECTIONS WELL: S-213A 02/03/05 1316 SIDETRACK "S -213A" 03/04 /13 JRP/JMD SET PORTED ISO SLV (02/11/13) PERMIT No: 2042130 (140) (150) (160) 170) 12/03/05 JPK/TlI. GLV C/O (02/24/05) AR No: 50- 029 - 22993 -01 (60) (61) (62) (63) 01/04106 JGMtTLH BKR ISO SLV SET SEC 35, T12N, R12E, 934' FNL & 780' FWL 02/18/08 TW /PJC FNAL DRLG DRAFT CORRECTIONS 08/24/09 7W /PJC FEFF DATE CORRECTIONS 1 BP Exploration (Alaska) Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth Well Job # Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 " Log Description Date BL Color CD Z-08A 8 5 81-0001 5 PRODUCTION PROFILE 3-27/M-33 88K5-00012 - / PRODUCTION PROFILE 10/25/09 1 2-34/P-14 S-213A V-227 06-181 L3-11 O-~B AWJI-00061 B8K5-00007 B69K-00036 B2NJ-00033 AP30-00065 B2NJ-00036 - / MEM INJECTION PROFILE U - GAS LIFT SURVEY / USIT U ZL° - / O MCNL L RST - MCNL 11/18/09 12/01/09 10/26/09 .11/19/09 10/12/09 10/31/09 11/04/09 1 1 1 1 1 1 1 H-OSB B2WY-00033 MCNL v 10/20/09 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G eNn taFTnewwr_ nwc ~nrw ~...~, r,._ tiN txploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2-1 900 E. Benson Blvd. N 2525 Gambell Street, Suite 400 f~/ + } ? ~ ~ ~ ~ ~ ~ f ~ ~ O / r ,r ~ ~ a r ^ ^ (~ ~ f,.~ Anchorage, AK 99503-2838 - s... - ?h.N ~. ~ 1 t)1(~ „ ~ ,P_ . i ~ BP Exploration (Alaska) Inc. Attn: Well integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, ~~~-~~3 _ ~.~,~ ~ ~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this fetter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. !f you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~:'~~~~~~~ v~i. ~ ~` 20~~ ~ ~,~E ~ `~s~~`~~~~~~:~. JUL ~ ~, 2009 ~~:4~~~~ (~~" ~~. C~;~ ~a~e~ G~~~rr~r~~sA~ ~an~~~~~°~~~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-oH Report of Sundry Operations (10-404) S-pad , ~ Dwte fi/25/2009 Well Name PTD # Initial rop of cement Vol. of cement um ed Final rop of cement Cemern rop off date Corrosion inhibitor Corcosion inhibirod sealant date it bbls ft na al S-Ot8 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 0.25 NA 025 NA 1.7 S/25/2009 5-03 7811900 1325 NA 13.25 NA 92.65 5/20/2009 S-oa 7830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26l2009 5-06 7821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 &OBB 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31l2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 7.7 6/i12009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 0.25 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA 025 NA 7.3 5/19/2009 S-2t 1900470 0.5 NA 0.5 NA 3.a 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1907270 025 NA 025 NA t.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/20D9 S•26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/3112009 S-29A~7 7960120 0 NA 0 NA o.e5 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.t 5/37/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 7921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .e5 in 5/31l2009 S36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 5-37 1920990 125 NA 125 NA ~ 1.9 5/27/2009 S-3B 1921270 025 NA 025 NA 102 5/27/2009 5-41 7960240 1.5 NA 1.5 NA 71.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/3W2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/29/2009 S-a4 1970070 025 NA 025 NA t.7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 1.25 NA 125 NA 11.9 5/29/2009 S-1021t 2031560 1.25 NA 125 NA 11.1 5/31/2009 5-703 2001680 1.5 NA 1.5 NA 11.9 5/1B/2009 5-~04 2001960 7.75 NA 7.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 16.25 NA 7625 NA 174.3 6/2/2009 5-107 2011130 225 NA 2.25 NA 28.9 5/78/2009 5-108 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-10s 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 1/.75 NA 11.75 NA 98.6 5/30/2009 S-~ 7 7 2050510 2 NA 2 NA 19.6 5/30/2009 S-t72 2021350 0 NA 0 NA 0.5 5/30/2009 S-713 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-71aA 2021980 125 NA 125 NA tOZ 5/30/2009 S-715 2022300 2.5 NA 2.5 NA 272 5/29/2W9 5-116 2031810 1.5 NA 1.5 NA 13.6 5/2B/2009 5-~77 2030120 7.5 NA 1.5 NA 15.3 5/29/2009 S-~~e 2032000 5 NA 5 NA 76.5 5/28/2009 S-~t9 2047620 1 NA 1 NA 52 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 7.5 NA 20.4 5/26I2009 5-124 2061360 1.75 NA 1.75 NA 11.9 5/2&2009 5-125 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 725 NA 15.3 &7/2009 S-200 1972390 125 NA 125 NA 14.5 5/28/2009 S-201 2001840 0 NA 0 NA 0.&5 6/19/2009 1 S-2t3A 2042730 2 NA 2 NA t3.6 5/29/2009 S-215 2021540 2 NA 2 NA ~8.7 6l1/2009 S-216 2007970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 025 NA 025 NA 1.7 6/1/2009 Sd00 2070740 2 NA 2 NA 9.4 5/2B/2009 S~a01 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 • • max; MICROFILMED 43/01/2tJ08 DO NOT PLACE '~ - . ,, y ANY NEW MATERIAL UNDER THIS .PAGE F:~LaserFiche~CvrPgs_InsertsuLticrofilm Marlcer.c~oc SChlu~~ergeP Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth c3:,1~5~p~g~ IV~ V ~ 0 ~Q~~ Well Job # Log Description N0.4409 Company: Alaska Oil 8 Gas Cons Comm AHn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Borealis Date BL Color CD V-203L1 40012957 OH EDIT MWD/LWD 01/24/06 2 1 V-112 40013154 0 OH EDIT MWDILWD V 03/02/06 2 1 Z-108 40012738 ~ OH EDIT MWDILWD 02/04/07 2 1 Z-100 NIA SBHP SURVEY 09115/07 1 5-213A 11855809 SBHP SURVEY 08/31/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Pefrotechnical Data Center LR2-1 F 900 E Benson Blvd. _ ? - Anchorage AK 99508-4254 Dafe Delivered: ~~ 3 v ~ fJ LIJQ 1 cr ;'atifllllfi+l~~91 ~, Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ ~`"~~~~/ 09120/07 • • v Permit to Drill 2042130 MD /' 12190· TVD REQUIRED INFORMATION ] f1CM... ~7 DATA SUBMITTAL COMPLIANCE REPORT 4/9/2007 Well Name/No. PRUDHOE BAY UN POL S-213A Operator BP EXPLORATION (ALASKA) INC 5220 /" Completion Date 2/3/2005/ Completion Status Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD / GR / RES / DEN / PWD, MWD / GR / RES / Azimuthal Den / N Well Log Information: Log/ Data ~ ~ rt I ~ Electr Digital Dataset Med/Frmt Number D Asc C Las Name Directional Survey Directional Survey See Notes 13468 Production ~ 13468 Production Blu ~ 14286 Induction/Resistivity 25 Blu dog 14286 Induction/Resistivity 25 Blu ¿.Æ6 C Lis 14286 Induction/Resistivity ~g Well Cores/Samples Information: Name G~ V'/".. ¿V-~,;._ Blu Interval Start Stop Sent Received 1-01L Current Status 1-01L .sP~ )CAPov~'? API No. 50-029-22993-01-00 UIC N Directional surve:~ (data taken from Logs Portion of Master Well Data Maint 4500 6860 2/2/2006 2856 12190 Open 12/13/2006 2856 12190 Open 12/13/2006 2856 12190 Open 12/13/2006 2678 5796 Qpe1'\" 3/22/2007 (¡t.,t.L Sample Set Number Comments e Comments Fluid Analysis on Bottomhole Samples/Black I Oil Full PVT Study Report PRODUCTION PROFILE PRESS/CCLlGRlFCAPITE MP/SPIN JEWELRY LOG plus PDF and TIFF graphics PRODUCTION PROFILE PRESS/CCLlGR/FCAPITE MP/SPIN MD Vision Service 11-Dec- 2006 W/Graphics TVD Vision Service 11- Dec-2006 w/Graphics LIS Veri GR, ROP, FET, DRHO, NPHI Mem Gas Lift Survey, Mem LEE, CCL , GR, Pres, Temp, Spin 14-Feb- 2007 e Log Log Run Interval OH/ Scale Media No Start Stop CH Received 0 12190 4/1/2005 0 12190 4/1/2005 0 0 5/27/2005 0 0 4500 6860 C ~!>u\. 2/2/2006 DATA SUBMITTAL COMPLIANCE REPORT 4/9/2007 Permit to Drill 2042130 Well Name/No. PRUDHOE BAY UN POL S-213A Operator BP EXPLORATION (ALASKA) INC MD 12190 Completion Date 2/3/2005 Current Status 1-01L TVD 5220 Completion Status 1-01L ADDITIONAL INFORMATION Well Cored? Y / ~ Daily History Received? ~N @N Chips Received? ~ Analysis ~ Received? Formation Tops API No. 50-029-22993-01-00 UIC N ~---- - ~~- ~~.~~~~ Comments: ~--~- -- Compliance Reviewed By: ~ Date: q rif-~7-~ e - SchlumÞerger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well L-213 W-204 W-205L2 S-213A_ V-105 -- (;)()t..(-é) 13 Job # Log Description 11212849 CH EDIT USIT (PDC-GR) 11630451 CEMENT BOND & IMAGE LOG 11626070 RSTIWFL 11628755 MEMORY GLS 11626370 IPROFILEIWFL 04/27/06 02102/07 02/05/07 02/14/07 01/29/07 --- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc Pelrolechnical Data Center LR2-1 900 E Benson Blvd Anchorage AK 99508~4254 Date Delivered .., l:-~; 'I,.' (;~ ( zom 03/13/07 NO" 4179 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Borealis Orion Date BL CD Color - ----- Schlumberger~DCS 2525 Gambell St SUlle 400 Anchorage AK 99503-2838. /:1 ::.::: ~¡¿~ e 12/11/06 SchlumbergeJl NO. 4070 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Prudhoe Bay Well Job # Log Description . V-211 40011188 OH EDIT OF MWD/LWD S-213A 40011201 OH EDIT OF MWD/LWD DS 09-13 11491394 MEM PROD PROFILE 14-3OA 11485775 MEM PROD PROFILE DS 09-36C 1149225 INJECTION PROFILE W-12A 11418301 MEM PROD PROFILE Y-29A 11485776 MEM PROD PROFILE NK-43 11414407 PROD PROFILE WIDEFT 6-13A 11212899 USIT 14-30A 11485775 SCMT DS 02-39L 1 11491395 SCMT Date BL Color CD 11/17104 2 12/11/04 2 11/24/06 2 11/21/06 2 11/23/06 2 09/10106 2 11/25/06 2 10/26/06 2 11/05/06 11/22/06 11/25/06 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd Anchorage AK 99508-4254 ECE\\/E]) Schlumberger-DCS 2525 Gambel! St, Suite 400 Anchorage, AK 99503-283 ATTN: Beth (\ Received by: L . Dale Delivered OEG 1 3 2006 i\lØ~ 01\ & C,a~ Co115. Cc¡mm\s,cMon -. .. AOO'I!.-~~ ¿x¿/-êJß ;# I L.l~ k" A STATE OF ALASKA A RE·CE·IVED ALASKA. AND GAS CONSERVATION COM~ION .. WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAR 1 0 ?nOí Ala$ka Oil & GII Con 1b. Well CIMchQrage 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204·213 13. API Number 50- 029-22993-01-00 14. Well Name and Number: . No. of Completions 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD I GR / RES I DEN / NEU / PWD, MWD I GR I RES / Azimuthal Den I NEU / AIM I PWD CASING, LINER AND CEMENTING RECORD SWING DEPTH MD SETTING DEPTH ND HOLE ., ()P BoTTOM Top BoTTOM SIZE Surface 110' Surface 110' 30" 28' 2859' 28' 2829' 12-114" 24' 6870' 24' 5264' 8-3/4" 6446' 12184 5198' 5220' 6-3/4" o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4347' NSL, 4501' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 2464' NSL, 1685' WEL, SEC. 34, T12N, R12E, UM (OBd) Total Depth: 2531' SNL, 1328' WEL, SEC. 03, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-_ 618930 . y- 5980550_. Zone-_~SP~__ TP/: x- 616498 y- 5978630 Zone- ASP4 Total Depth: x- 616941 y- 5973640 Zone- ASP4 -~--------------- ----------~---- --------~- 18. Directional Survey 181 Yes 0 No 22. CASING SIZE Wr. PER FT. 94# 40# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 20" 9-5/8" 7-5/8" 4-1/2" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 6868' -12141' 5264' - 5220' 26. Date First Production: March 8, 2005 Date of Test Hours Tested PRODUCTION FOR 3/8/2005 4 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ..... Press. 300 1,700 24-HoUR RATE""" One Other 5. Date Comp., Susp., or Aband. 2/3/2005 6. Date Spudded 11/25/2004 7. Date T.D. Reached 12/11/2004 8. KB Elevation (ft): 61.82' 9. Plug Back Depth (MD+ TVD) 12190 + 5220 10. Total Depth (MD+TVD) 12190 + 5220 11. Depth where SSSV set (Nipple) 2255' MD 19. Water depth, if offshore N/A MSL 24. SIZE 4-1/2",12.6#, L-80 PBU S-213A 15. Field I Pool(s): Prudhoe Bay Field / Polaris Pool Ft Ft 16. Property Designation: ADL 028253 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 260 sx Arctic Set (Approx.) 440 sx AS Lite III, 215 sx Class 'G' 229sx Class 'G' Uncemented Slotted Liner TUBING RECORD DEPTH SET (MD) 5961' PACKER SET (MD) 5844' 25. ACID, FRACTURE,CEMENrSOUEEZE,ßC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 100 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BBL GAs-McF WATER-BBL 122 23 29 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). ~~.i!.C:9re{hiPS; if none, state "none". N0~~3§h- .,~; . I: .... 1 .,...,-. -.,.,-..-..-.,,;;;,-._,:.:'_.'~ . OIL -BBL 732 27. Form 10-407 Revised 12/2003 GAs-McF 138 WATER-BBL 174 CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO 19.33° 189 OIL GRAVITY-API (CORR) RBDMs 8Ft MAR 1 4 Z005 ~~ (;;)' 28. GEOLOGIC MARKER. NAME MD Ugnu 3816' Ugnu MA 5453' Ugnu MB1 5522' Ugnu MB2 5584' Ugnu MC 5706' Schrader Bluff NA 5810' Schrader Bluff NB 5841' Schrader Bluff NC 5858' Schrader Bluff OA 5996' Schrader Bluff OBa 6109' Schrader Bluff OBb 6208' Schrader Bluff OBc 6399' Schrader Bluff OBd 6748' Schrader Bluff OBe 6912' Schrader Bluff OBe 7201' 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TVD 3549' 4726' 4774' 4817' 4896' MDT was ran, log supplied for detail. 4958' 4975' 4985' 5055' 5105' 5140' 5189' 5247' 5267' 5258' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble~efV\.i.R. . ~ Title Technical Assistant Date 03 -/0- 05 PBU S-213A 204-213 Prepared By NameINumber: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Michae/ Trio/a, 564-5774 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). 'TEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 'TEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. 'TEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). 'TEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). 'TEM 27: If no cores taken, indicate "None". 'TEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only S-213A MDT Client BP Exploration Inc Tool pa/ps/lf/scIJo/sc/po/sc/sc/ms/pc Well S-213A Spec D,weather Date 11/29/04 SO File Time Deplh Zone Tool TVD Temp Prelesl Mob Before Formation After Flow presure Pump V pump.time TeslType/commenl 5 12:14 5176 ps 90 20 2296 2158 2295 1001 check 7 correlalion 15 8 correlalion -- 19 14:30 5531 Mbl ps 94 20 2.4 2340 2293 2339 ¡¡ood lest 21 15:00 5630 Mb2 ps 94 20 2387 lost seal could nol hold set persure 22 15:20 5631 Mb2 ps 94 20 2383 losl seal could nol hold set persure 24 15:30 5728 Mc ps 95 20 4.1 2425 2198 2411 ¡¡ood lesl 25 1600 5744 Mc ps 95 20 2425 losl seal could not hold set persure 26 16:15 5745 Mc ps 96 20 2418 2414 lost seal 27 16:29 5747 Mc ps 96 20 108.2 2427 2200 2416 good lesl 28 16:50 5748 Nb ps 96 20 2449 los seal 29 17:03 5849 Nb ps 96 20 17.1 2446 2114 2443 ¡¡ood test 30 17:30 6000 Oa ps 97 20 38.9 2492 2081 2483 good test 31 17:40 6031 Oa ps 97 20 2500 2491 lost seal 32 17:50 6032 Oa ps 97 20 2493 -- losl seal 33 18:00 6060 Oa ps 98 20 8.2 2505 2110 2494 ¡¡ood tesl 34 18:20 6117 Oba ps 98 20 2509 lost seal . 35 18:40 6118 Oba ps 98 20 2511 2507 - losl seal could not hold set persu;:e- 36 19:00 6214 Obb ps 99 20 2535 2524 losl seal 37 19:22 6215 Obb ps 99 20 2527 2523 losl seal 38 19:37 6235 OBb ps 100 20 30.9 2539 2062 2524 ¡¡ood lest 39 19:55 6247 OBb ps 100 20 8.8 2542 2067 2525 good lest 40 21:00 6402 Obc ps 100 20 2565 2554 dry lesl 41 21:00 6403 Obc ps 100 20 2556 2549 losl seal 42 21:27 6424 Obc ps 101 20 2567 2551 lost seal 43 21:40 6525 Obc ps 101 20 2556 2550 lost seal 45 2145 6491 Obc ps 102 20 2565 2559 losl seal 46 21:56 6492 Obc ps 102 20 2565 2556 dry lest 47 22:05 6496 Obc ps 102 20 2569 2555 -~ dry test 48 22:12 6497 Obc ps 102 20 2563 2556 losl seal 49 22:24 6498 Obc ps 102 20 2563 2555 dry lesl 50 23:21 6824 Obd ps 103 20 2600 2581 lost seal 51 23:32 6825 Obd ps 103 20 2593 2582 lost seal 52 23:47 6820 Obd ps 103 20 245 2577 2083 2577 ¡¡ood lesl 54 ..:30 «3824 Obd pa 102 2582 2579 54990 63 . MRSC.:;!43 pump up to 4000 psi gal.OilSarnple 66690 ·..·1 70. pump up 10. 4000 psi ··.:Iols of Gas: .......;..:.1.;..;.. 8EL. ..... PlJIT1P'upj04()(jOpsi: . 59 8:13 6496 000 pa 99 2555 2559 700 10·120 15795 60 could.nol flow . 60 9:54 6491 Obc pa 101 2568 2558 700 10 50 30 could nolflow 61 11:20 6424 000 pa 101 2581 2556 700 1050 27 coWd nOI floW 62 12:05 6403 ........... ..i.::j·( ..··60..> MPSR.13!:18:! PuITI¡:ìoþIO.4000psi; . 450 Cc (Iii sample I 60 :·MPRS.1399 (...!(. puITI¡:ì\Jpio 4()(jOp$i ... 450 cò oil såmple ..... 56895:1· 90 450 Cc(lilsarnple pump lJpto4000.psi MPSR·1400 90675 :··1··.·. 80 MPSR,140f pumP'ÚpI04000 psi 450Ccoil sample 68 I 75 pump tip to 4000 psi .... S-213A MDT Fluid Properties Sample ID Cylinder # Depth Sand GOR Molar Mass Density API (ft) sef/stb (glee) 1.01 CSB 7759-QA 6,824 OBd 310 268.3 0.91 24.1 1.02 CSB 7763-QA 6,824 OBd 307 269.1 0.91 24 1.04 CSB 7476-MA 6,177 OBa 234 332.5 0.941 18.8 1.05 CSB 7735-QA 6,177 OBa 225 333.2 0.942 18.8 gas and water/filtrate 1.07 CSB 7753-QA 6,000 OA-Upper 15,670 175 0.836 37.7 only - no oil . 1.08 CSB 7755-QA 6,403 OBe 291 263 0.907 24.5 1.09 CSB 7690-QA 6,247 OBb 260 282.7 0.917 22.8 1.10 CSB 7761-QA 6,059 OA-Lower 212 308.9 0.936 19.7 1.11 CSB 7725-QA 5,747 Me 194 457.9 0.972 14 1.12 CSB 7680-QA 5,531 Mb1 203 480.4 0.98 12.9 . Legal Name: S-213 Common Name: S-213 1/3/2001 11/25/2004 12/8/2004 FIT LOT FIT 2,858.0 (ft) 2,856.0 (ft) 6,870.0 (ft) 2,838.0 (ft) 2,828.0 (ft) 5,265.0 (ft) 10.50 (ppg) 9.20 (ppg) 9.00 (ppg) 300 (psi) 820 (psi) 411 (psi) 1,848 (psi) 2,172 (psi) 2,873 (psi) 12.53 (ppg) 14.78 (ppg) 10.50 (ppg) . . Printed: 2/7/2005 9:37:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 11/17/2004 05:00 - 07:00 2.00 MOB P PRE Move rig off from J-02b. 07:00 - 07:30 0.50 MOB P PRE Pre-move safety meeting with Tool Service, Security and all rig personnel reviewing pre-move route inspection and all rig move hazards. 07:30 - 15:00 7.50 MOB P PRE Move rig from J·Pad to S-Pad. Security stopped rig move for 2 hrs to clear the road allowing personnel to respond to Z-Pad. 15:00 - 00:00 9.00 MOB P PRE Work on cellar door and flowline mods 11/18/2004 00:00· 00:00 24.00 MOB P PRE Continue rig mods, cellar doors and flow line. Install vacuum system lines and controls. 11/19/2004 00:00 - 04:30 4.50 MOB P PRE RD flowline platform and scud launcher. 04:30 . 12:00 7.50 MOB P PRE Spot rig over S-213. Spot and RU pit, pump and generator I modules. I RIG ACCEPTED @ 12:00 HRS 12:00 . 13:00 1.00 WHSUR P DECOMP RU to tree to circulate. 13:00 . 15:30 2.50 KILL P DECOMP Take on seawater. RU scaffolding in cellar. Berm rig. 15:30 - 16:30 1.00 WHSUR P DECOMP PJSM. RU DSM and pull BPV through lubricator. RD DSM. 16:30 . 17:00 0.50 WHSUR P DECOMP Hold pre-spud meeting with crew and all service personnel. Review well hazards and SOR. 17:00 - 20:00 3.00 KILL P DECOMP RU lines and pressure test to 2900 psi. Reverse circulate 20 bbls through choke using cellar manifold to remove freeze protect diesel from the tbg. Started taking mixed diesel and crude oil returns to cuttings box. Switched manifold and circulated a 40 bbl detergent sweep surface to surface holding 100-150 psi choke pressure to circulate diesel out of annulus. Circulate a second 40 bbl detergent sweep around to clean up tbg and csg. 20:00 - 21 :00 1.00 KILL P DECOMP Shut in choke and kill lines. monitoring pressure. RD and blow down lines. 0 pressure, open choke and flow check well for 15 minutes. 21 :00 - 00:00 3.00 WHSUR P DECOMP PJSM. ND tree and adapter flange. Break out tree and set behind well. 11/20/2004 00:00 - 01 :00 1.00 WHSUR P DECOMP Break out adapter flange and set out of cellar behind well. Enclose rig cellar with tarps. 01 :00 - 08:00 7.00 BOPSUF P DECOMP NU BOPE. Install HCR valves. Hook up choke & kill lines to HCR valves. NU riser & flow line. RU floor drain lines to flowline manifold. 08:00 - 08:30 0.50 BOPSUF P DECOMP PJSM with all rig personnel on testing BOPE. 08:30 . 09:00 0.50 BOPSUF P DECOMP RU BOP test equipment 09:00 - 12:00 3.00 BOPSUP P DECOMP Test BOPE to 250/3500 psi. Unable to test lower pipe rams with tbg hanger in the hole. Witness of test waived by John Crisp with AOGCC. 12:00 - 12:30 0.50 BOPSUP P DECOMP RD BOP test equipment. Blow down lines. 12:30 - 13:30 1.00 WHSUR P DECOMP PJSM. RU DSM and pull TWC through lubricator. RD DSM 13:30 - 14:30 1.00 PULL P DECOMP RU tbg equipment to pull 3-1/2" completion. 14:30 - 15:00 0.50 PULL P DECOMP MU DP with XO to 4-1/2" NSCT tbg hanger. BOLDS. PU 78k and unseat tbg hanger. Up weight w/ tbg 77k. Pull hanger to floor. 15:00 - 16:30 1.50 PULL P DECOMP Break out and LD tbg hanger. MU to tbg and circulate 40 bbl detergent sweep around while reciprocating tbg 16:30 - 17:00 0.50 PULL P DECOMP PJSM with rig crew on pulling and laying down tbg, Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 11/20/2004 17:00 - 23:30 6.50 PULL P DECOMP Pull and LD 3-1/2" completion. Losses averaging 6-7 bph while pulling tbg. Recovered: 1- jt 4-1/2" tbg 161 - jts 3-1/2" tbg 3 - GLM's 1 - "X" Nipple 1 - 18.71' cut joint of 3-1/2" tbg 23:30 - 00:00 0.50 BOPSUPP DECOMP Monitor well. RU test equipment. Set test plug and fill stack. 11/21/2004 00:00 - 01 :00 1.00 BOPSUF P DECOMP Test lower pipe rams 250/3500 psi. RD test equipment. 01 :00 - 02:00 1.00 PULL P DECOMP Clear tbg handling equipment from rig floor. Clean rig. 02:00 - 03:00 1.00 CLEAN P DECOMP Install wear bushing. PU BHA #1, 6-1/8" clean-out assembly. 03:00 - 08:30 5.50 CLEAN P DECOMP RIH to 5241' with clean out assy picking up 4" DP from pipe shed. Fill DP and break circulation every 25 stands. 08:30 - 09:00 0.50 CLEAN P DECOMP Wash down from 5241' to tbg stub at 5265'. 5 bpm @ 550 psi 09:00 - 10:00 1.00 CLEAN P DECOMP Circulate 20 bbl detergent sweep followed 40 bbl h-vis sweep. Continue circulating to get sweeps out of the hole and clean returns. Losses averaging 6 bph. 5 bpm @ 550 psi 10:00 - 13:00 3.00 CLEAN P DECOMP Monitor well - level dropping. POH with clean-out assy P/U 107k Ibs S/O 105k Ibs 13:00 - 13:30 0.50 CLEAN P DECOMP LD 6-1/8" clean out BHA. 13:30 - 14:00 0.50 CLEAN P DECOMP Service rig, drawworks, crown, blocks and iron roughneck 14:00 - 15:00 1.00 DHB P DECOMP MU HES 7" EZSV bridge plug assembly. 15:00 - 17:30 2.50 DHB P DECOMP RIH to 5220' 17:30 - 18:00 0.50 DHB P DECOMP Break circulation. POH to 5200 and set EZSV. 18:00 - 18:30 0.50 DHB P DECOMP Pressure test EZSV to 1000 psi. 18:30 - 20:30 2.00 PXA N CEMT DECOMP Circulate while waiting for cement to be re-batched and sent to location. Testing of original cement showed a two hour set time, was sent back to the plant to be re-blended with a minimum 3 hr set time. 20:30 - 21 :00 0.50 PXA P DECOMP PJSM with Schlumberger, MI, Veco and all rig personnel on mixing and pumping cement. 21 :00 - 21 :15 0.25 PXA P DECOMP Pump 5 bbls water to fill lines. pressure test cement lines to 3500 psi. 21 :15 - 21 :30 0.25 PXA P DECOMP Batch mix and pump 11 bbls (66 sxs) 15.7 ppg, Arctic Set I cement. Chase with 10 bbls of water behind cement to flush lines. 21 :30 - 22:00 0.50 PXA P DECOMP Switch to rig pump and displace cement with 49 bbls seawater. 22:00 - 22:30 0.50 PXA P DECOMP POH with 5 stands to 4700' 22:30 - 23:15 0.75 PXA P DECOMP Circulate clean seawater around to ensure DP is free of cement. 5 bpm @ 300 psi 23:15 - 00:00 0.75 PXA P DECOMP Displace well to 9.5 ppg used LSND mud. 5 bpm @ 490 psi 11/22/2004 00:00 - 02:00 2.00 PXA P DECOMP Pump dry job, blow down top drive. POH with setting tool Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 11/22/2004 02:00 - 04:00 2.00 PXA P DECOMP MU EZSV #2 and RIH to 3155' 04:00 - 04:30 0.50 PXA P DECOMP PU to 3150' and set EZSV. P/U 84k Ibs S/O 80k Ibs 04:30 - 06:00 1.50 PXA P DECOMP Blow down top drive and POH with setting tool. 06:00 - 07:00 1.00 STCTPL P DECOMP Pull wear bushing and rig up double valve on 9-5/8" X 7" annulus. 07:00 - 09:00 2.00 STCTPL P DECOMP MU BOT csg cutter assembly and RIH to 2950' 09:00 - 10:00 1.00 STCTPL P DECOMP Position cutters @ 2950'. Cut 7" csg. 10:00 -11:00 1.00 STCTPL P DECOMP Establish circulation through 9-5/8" X 7" annulus. Circulate -50 bbls dead crude out of well. 11:00 -13:30 2.50 STCTPL P DECOMP Displace annulus to hot seawater followed by 100 bbl detergent sweep. Then displace annulus to 9.4 ppg LSND mud 4 bpm @ 950 psi 13:30 - 14:00 0.50 STCTPL P DECOMP Pull 1 stand, MU spear assembly and spear 7" csg. BOLDS 14:00 - 15:00 1.00 STCTPL P DECOMP Pull of to 350k Ibs, establish circulation and work casing pulling up to 375k Ibs. Able to pull csg 3' up hole. 15:00 - 16:30 1.50 STCTPL P DECOMP Attemp to work casing back down. Able to work hanger down to 1.5' above ring. 16:30 - 17:00 0.50 STCTPL P DECOMP Release spear. LD spear assy. 17:00 - 19:00 2.00 STCTPL P DECOMP POH and LD csg cutter assembly. 19:00 - 21 :30 2.50 STCTPL P DECOMP PU spear assy and spear 7" csg. Establish circulation, 4 bpm @ 450 psi. Work casing picking up to 375k Ibs. Work csg 5' uphole. Packing off, no returns. Continue working csg picking up to 400k Ibs and attempting to regain circulation. NO progress. Un spear and LD spear assy. 21 :30 - 23:00 1.50 STCTPL P DECOMP PU csg cutter and RIH to 2915'. 23:00 - 00:00 1.00 STCTPL P DECOMP Rig service, inspect top drive. 11/23/2004 00:00 - 00:30 0.50 STCTPL P DECOMP Pump cutter knives open, RIH and tag csg collar at 2913'. PU l' to 2912' and cut csg. Cut at 2912',53' below 9-5/8" csg shoe. 00:30 - 02:00 1.50 PXA P DECOMP Pump dry job, blow down top drive. POH with csg cutter assy. 02:00 - 02:30 0.50 STCTPL P DECOMP PU csg spear and change out grapple. RIH and spear 7" csg. 02:30 - 03:00 0.50 STCTPL P DECOMP PU to 375k, attempt to establish circulation, packed off. Continue working csg, attempting to circulate. Csg finally came free at 395k Ibs. Establish circulation, 3 bpm @ 300 psi. 03:00 - 03:30 0.50 STCTPL P DECOMP CBU 4 bpm @ 300 psi. 03:30 - 04:00 0.50 STCTPL P DECOMP Pull csg hanger to the rig floor. Rig up csg equipment while circulating, 4 bpm @ 300 psi. 04:00 - 04:30 0.50 STCTPL P DECOMP break out and LD csg spear. Blow down top drive. CO elevators. 04:30 - 05:00 0.50 STCTPL P DECOMP PJSM with all rig personnel on breaking out and laying down csg. 05:00 - 10:30 5.50 STCTPL P DECOMP Pull and UD 69 jts of 7" csg, 29' of cut off jt, casing pup below hanger 10:30 - 11 :30 1.00 STCTPL P DECOMP UD casing equipment, P/U spear, make service breaks, UD spear 11 :30 - 13:00 1.50 CLEAN P DECOMP Clear and clean floor. 13:00 - 14:00 1.00 CLEAN P DECOMP Service rig and topdrive, lubricate and inspect crown. 14:00 - 15:30 1 .50 CLEAN P DECOMP Change out saver sub on topdrive. 15:30 - 17:00 1.50 WHSUR P DECOMP Install double valve, flange and gauge on OA annulus. 17:00 - 20:00 3.00 REMCM-P DECOMP P/U 30 jts of 3.5" tubing, RIH with 4" DP, tag EZSV at 3,150', Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 11/23/2004 17:00 . 20:00 3.00 REMCM-P DECOMP pull up to 3,143' UD joint of DP. 20:00 - 20:30 0.50 REMCM-P DECOMP M/U TIW valve and cement hose, CBU 5 bpm @ 300 psi, up wt = 75k, dn wt = 75k, held PJSM with all rig personnel andcementers, while circulating, 20:30 - 21 :00 0.50 REMCM-P DECOMP Pump 5 bbls water and test lines to 2,500 psi, pump remaining 13 bbls at 5 bpm @ 360 psi, pump 65 bbls 17 ppg class G cement,S bpm 320 psi, pump 2.5 bbls water behind, and displace cement with rig pumps at 5 bpm 250 psi, pumped calculated strokes to balance plug, 15 bbls, 176 strokes. CIP @ 21 :00 hrs. 21 :00 - 21 :30 0.50 REMCM-P DECOMP POH slowly to 2,174' 21 :30 - 22:30 1.00 REMCM-P DECOMP M/U topdrive, break circulation @ 1 bpm, increased rate to 6.5 bpm 270 psi circulate hole clean, no cement to surface. 22:30 - 23:30 1.00 REMCM-P DECOMP Pump dry job, POH to 955' 23:30 - 00:00 0.50 REMCM-P DECOMP R/U and lay down 3.5" tubing. 11/24/2004 00:00 - 01 :00 1.00 REMCM-P DECOMP Continue laying down 30 joints 3.5" tubing 01 :00 - 02:00 1.00 REMCM-P DECOMP Rig down tubing handling equipment, Install wear ring, Clean floor 02:00 - 05:00 3.00 REMCM-P DECOMP Pickup 3 DCs, 14 joints 4" HW, Jars, and 39 jts 4" DP. 05:00 - 06:00 1.00 REMCM-P DECOMP POH stand back 13 stands DP 5 stands HW. 06:00 - 06:30 ' 0.50 REMCM-P DECOMP Make up 8 3/4" milltooth bit, clean floor 06:30 - 07:30 1.00 REMCM-P DECOMP RIH with clean out assembly to 1,990' 07:30 - 09:30 2.00 REMCM-P DECOMP Circulate @ 1,990' 2 bpm, 130 psi, while wait on cement. 09:30 - 12:00 2.50 REMCM-P DECOMP Wash from 1,990' tag top of cement at 2,203', Drill cement from 2,203' to 2,285', 10-25k wob, 410 gpm, 670 psi, 80 rpm, torque 3-4k, 40-60 fph. 12:00 - 21 :30 9.50 REMCM-P DECOMP Continue drilling cement from 2,285' to 2750' 20-28k wOb, 415 gpm, 700 psi, 80 rpm, torque 4-5k, 40-60 fph. up wt = 95k, dn wt = 85k, rt wt = 90k 21 :30 - 22:00 0.50 REMCM-P DECOMP Circulate bottoms up, 415 gpm @ 700 psi. 22:00 - 23:00 1.00 REMCM-P DECOMP POH with clean out assmbly 23:00 - 00:00 1.00 REMCM-P DECOMP Break bit, stand back DCs. 11/25/2004 00:00 - 03:30 3.50 CLEAN P DECOMP Make up 8 3/4" drilling assembly, orient MWD and motor, PJSM handling sources, load sources and pickup remaining BHA, surface test MWD at 640', flow rate 460 gpm @ 875 psi. 03:30 - 04:30 1.00 CLEAN P DECOMP RIH with 8 3/4" drilling assembly, position Ghost reamers @ +/- 1,000 and +/- 2,000' per directioal driller, continue RIH to 2694' 04:30 - 05:00 0.50 CLEAN P DECOMP Make up topdrive, break circulation, wash from 2,694' to 2,750' 380 gpm 710 psi. 05:00 - 06:30 1.50 CLEAN P DECOMP Drill cement from 2,750' to 2856' 380 gpm, 780 psi, 50 rpm, torque 4500 ftllbs. 80 to 90 fph. 06:30 - 12:00 5.50 STCTPL P DECOMP Time drill off cement plug, from 2,856' to 2,886',3 fph for 3',5 fph for 10',10 fph for 17' maintaining a 15L toolface, 390 gpm, 1,240 psi on bottom, 1,100 psi off bottom, up wt = 97k, dn wt = 95k 12:00 - 14:30 2.50 STCTPL P DECOMP Continue drilling from 2,886' to 2,932', maintaining 50 psi differential pressure on motor, holding 15 to 20L toolface, began rotating from 2,932' to 2,962', 2k wob, 60 rpm, torque 4.5k, 425 gpm, 1,400 psi on bottom, 1,280 psi off bottom. 14:30 - 15:30 1.00 STCTPL P DECOMP Displace well to 9.2 ppg LSND mud, @ 425 gpm, 1,260 psi. 15:30 - 16:30 1.00 DRILL P INT1 Pull back inside casing to 2,758', rig up and perform LOT, 2,856 md, 2,828' tvd, mud wt 9.2 ppg, pressure attained 820 psi, EMW 14.7. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 11/25/2004 16:30 - 17:00 0.50 DRILL P INT1 RIH to 2,950' obtain clean hole ECD @ 400 & 600 gpm, 60 rpm, clean hole ECD = 9.53. 17:00 - 21 :00 4.00 DRILL P INT1 Directional drill 8 3/4" hole from 2,962' to 3,463', wob 2-5k, 570 gpm, 1,650 psi on bottom, 1,500 psi off bottom, 60 rpm, torque 5 k on bottom 4.5k off bottom, up wt = 104k, dn wt = 94k, st wt = 100k, ECD = 9.75. When pumping 600 gpm, losing mud over shakers, change screens during connection. While making connection hydraulic hose on topdrive started leaking, 21 :00 - 00:00 3.00 DRILL N RREP INT1 POH to 2,789', blow down topdrive, Repair hose on topdrive. 11/26/2004 00:00 - 03:00 3.00 DRILL N RREP INT1 Repair topdrive, RIH to 3,463' 03:00 - 12:00 9.00 DRILL P INT1 Directional drill 8 3/4" hole from 3,463' to 4,422', wob 2-10k, 570 gpm, 1,830 psi on bottom, 1,730 psi off bottom, 80 rpm, torque 6-7 k on bottom 4-5k off bottom, up wt = 111k, dn wt = 100k, st wt = 102k, ECD = 9.95 AST = .70 ART = 3.08 12:00 - 22:30 10.50 DRILL P INT1 Directional drill 8 3/4" hole from 4,422' to 5,480', wob 10-20k, 550 gpm, 2,250 psi on bottom, 1,990 psi off bottom, 100 rpm, torque 6-7 k on bottom 5-6k off bottom, up wt = 130k, dn wt = 110k, st wt = 120k, ECD = 10.04 calculated clean hole ECD = 9.54 22:30 - 23:30 1.00 DRILL P INT1 Pump 20 bbllow vis sweep, followed by 20 bbl high vis weighted (10.2 ppg) sweep at 550 gpm 1,990 psi, rotating string 100 rpm, 4.5k torque, pumped sweep in order to keep ECD at or below the .60 ppg over clean hole limit through this section. 23:30 - 00:00 0.50 DRILL P INT1 Directional drill 83/4" hole from 5,480' to 5,495', wob 10-20k, 550 gpm, 2,250 psi on bottom, 1,990 psi off bottom, 100 rpm, torque 6-7 k on bottom 5-6k off bottom, up wt = 130k, dn wt = 110k, st wt = 120k, ECD = 9.92 calculated clean hole ECD = 9.48 ART = 3.55 AST = .90 11/27/2004 00:00 - 12:00 12.00 DRILL P INT1 Directional drill 8 3/4" hole from 5,495' to 6,125", wob 2-1 Ok, 550 gpm, 2,100 psi on bottom, 1,900 psi off bottom, 100 rpm, torque 6-7 k on bottom 5-6k off bottom, up wt = 135k, dn wt = 115k, st wt = 125k, ECD = 9.90 when sliding 10.04 when rotating. Having to cycle pumps several times to get survey, clean suction screens and check pulsation dampner pressure on both pumps during connection, seemed to help. Continue to backream slowly on connections to keep ECD within set parameters. ART = 1.35 AST = 5.72 12:00 - 18:30 6.50 DRILL P INT1 Directional drill 8 3/4" hole from 6,125' to 6,485', wob 5-15k, 565 gpm, 2,240 psi on bottom, 2,110 psi off bottom, 100 rpm, torque 8-9 k on bottom 7-8k off bottom, up wt = 130k, dn wt = 107k, st wt = 116k, ECD = 10.0. Developed leak on topdrive gear box oil cooler. ART = .64 AST = 3.46 18:30 - 19:30 1.00 DRILL N RREP INT1 Blow down topdrive, made up circulating head, circulate @ 50 gpm, 240 psi, while trouble shooting problem. Decision was made to pull to shoe to make repairs. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 11/27/2004 19:30 - 22:00 2.50 DRILL N RREP INT1 POH from 6,485' to 2,866', pulled 20k over at 5,652' wiped through one time, no excess drag pulling back through, pulled to the shoe with no problems. hole took proper fill. 22:00 - 00:00 2.00 DRILL N RREP INT1 Remove oil cooler from topdrive,take to shop for repairs, clean oil from topdrive and windwalls, clean floor. 11/28/2004 00:00 - 02:00 2.00 DRILL N RREP INT1 Clean rig floor and topdrive, unable to repair oil cooler bypass cooler, fill gear box with oil took 10 gallons to fill. Test run topdrive and check for leaks. 02:00 - 03:30 1.50 DRILL N RREP INT1 RIH from 2,866' to 6435' no problem filled pipe @ 5,580' 03:30 - 03:45 0.25 DRILL P INT1 Make up Topdrive, break circulation, ream from 6,435' to 6,485' no fill 03:45 . 09:00 5.25 DRILL P INT1 Directional drill 8 3/4" hole from 6,485' to 6,880', 5-7k wob, 545 gpm, 2,340 psi on bottom, 2,240 psi off bottom, 100 rpm, 8-9k torque on bottom, 6-7k off bottom, up wt = 135k, dn wt = 100k st wt = 112k, ECD = 9.92. At bottoms up saw some trip gas LEL 80 ppm. ART = 1.55 AST = 1.11 09:00 - 09:30 0.50 DRILL P INT1 Circulate bottoms up @ 545 gpm, 2,400 psi, 100 rpm, 8-9k torque, reciprocate full stand. 09:30 - 13:00 3.50 DRILL P INT1 MAD pass from 6,880' to 5,872', pumping 550 gpm, 2,400 psi, 100 rpm, 8k torque, 600 fph. 13:00 - 13:30 0.50 DRILL P INT1 RIH fro 5,872' to 6,880' no problem going in hole. 13:30 - 15:00 1.50 DRILL P INT1 Pump 20 bbllow vis sweep, 20 bbl high vis weighted sweep, 575 gpm, @ 2,600 psi, 110 rpm, 9k torque, sweep brought back a significant amount of cuttings. 15:00 . 19:00 4.00 DRILL P INT1 Monitor well, POH to BHA no hole problems, monitor well at BHA 19:00 - 22:00 3.00 DRILL P INT1 Rack back HW and jars, RIB DCs, PJSM handling sources, remove sources, down load MWD, UD bit motor and MWD. 22:00 - 23:30 1.50 DRILL P INT1 Clear floor of all directional tools, clean floor 23:30 - 00:00 0.50 EV AL P INT1 Remove snow from pipe shed ramps, load MDT logging tools in pipe shed. 11/29/2004 00:00 - 00:30 0.50 EV AL P INT1 Continue loading pipe shed with Schlumberger MDT tools 00:30 - 01 :00 0.50 EV AL P INT1 PJSM with all rig personnel, Co Rep, Toolpusher, Schlumberger crew, picking up logging tools. 01 :00 - 03:00 2.00 EVAL P INT1 Make up MDT logging tools per Schlumberger representative. 03:00 . 03:30 0.50 EVAL P ,INT1 Latch up docking head and test logging tools. Rig up wire line sheave in derrick, make up xo to logging tools. 03:30 - 10:00 6.50 EVAL P INT1 RIH with MDT tools on 4" DP 1 min per/ stand fill DP @ 2,859', fill every 5 stands in open hole, RIH to 5,293' 10:00 - 12:00 2.00 EVAL P INT1 Pickup single of 4" DP, make up xo's and side entry sub, RIH with e-line, pumping @ 20 gpm to latch up head. Up wt = 105k, dn wt = 90k. 12:00 - 12:30 0.50 EV AL P INT1 Test MDT tool string, and side entry sub packoff. 12:30 - 00:00 11.50 EVAL P INT1 Logging with Schlumberger, taking pressure samples as directed by on site Geologist, took a total of 31 samples, 22 attempts failed due to lost seal or dry sample. The 9 samples that were recorded were from the following depths. Up wt = 140k, Dn wt = 100k. Mb1 - 5,531' Me - 5,728' Mc . 5,747' Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 11/29/2004 12:30 - 00:00 11.50 EV AL P INT1 Nb - 5,849 OA - 6,000' OA - 6,060' OBb - 6,235' OBb - 6,247' OBd - 6,820' 11/30/2004 00:00 - 22:00 22.00 EV AL P INT1 - Run MDT logs taking fluid samples @ depths per on-site Geologist. Good fluid samples @ 8 of 11 stations. 6824' - good sample in OBd 6117' - good sample in OBa 6000' - good sample in OA 6496' - no good - OBc 6490' - no good - OBc 6424' - no good - OBc 6403' - good sample in OBc 6247' - good sample in OBd 6060' - good sample in OA 5748' - good sample in Mc 5532' - good sample in Mb1 - Rig crew trained on vacuum system usage while logging. - Full derrick inspection completed. - RA tags inserted in cementralizers on 4 jts of 7 5/8" casing. 22:00 - 22:30 0.50 EV AL P INT1 - POH to 5293'. 22:30 - 00:00 1.50 EVAL P INT1 - R/D side entry sub & XO's. 12/1/2004 00:00 - 00:30 0.50 EV AL P INT1 - Break circ - monitor well. - Pump dry job - B/D TD. 00:30 - 03:00 2.50 EV AL P INT1 - POH to logging tools. 03:00 - 05:30 2.50 EV AL P INT1 - B/O & UD logging tools. 05:30 - 06:00 0.50 EV AL P INT1 - Clear & clean rig floor. 06:00 - 08:00 2.00 EV AL P INT1 - M/U clean out BHA consisting of: 83/4" FDS+VC mill tooth bit, NB stab w/ float, PWD, MWD, NM XO, NM spiral DC, NM stab, 2 NM spiral DC's, float / saver sub, jars, XO & 14 jts HWDP. - RIH to 830' & shallow test MWD. 450 GPM - 650 psi. 08:00 - 09:00 1.00 EVAL P INT1 - RIH w/ BHA on 4" DP to 2821' & fill pipe. 09:00 - 10:00 1.00 EVAL P INT1 - PJSM - slip & cut 85' drilling line. 10:00 - 10:30 0.50 EV AL P INT1 - Service & lubricate rig. 10:30 - 11 :00 0.50 EV AL P INT1 - RIH w/ BHA on 4" DP to 3495'. 11 :00 - 11 :30 0.50 EV AL P INT1 - CBU @ 400 GPM, 770 psi, 40 RPM. - B/D TO. 11 :30 - 14:00 2.50 EVAL P INT1 - RIH to TD @ 6880' washing down last 90' & breaking circ @ 5000'. P/U WI 145K, S/O WI 95K on bottom - Washed & worked through tight spots @ 6063',6120',6250' & 6821 '. 14:00 - 16:30 2.50 EV AL P INT1 - Pump & circ around 20 bbllow- vis weighted sweep followed by 20 bbl hi-vis sweep @ 600 GPM, 2540 psi, 120 RPM. CBU x 3. - Monitor well - spot lube-tex pill & pump dry job. 16:30 - 19:30 3.00 EVAL P INT1 - POH w/ clean out assy to BHA - hole slick. 19:30 - 21:30 2.00 EVAL P INT1 - UD BHA & clear floor. - Drain stack. 21 :30 - 22:00 0.50 BOPSUP P INT1 - Pull bowl protector & install test plug. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12/1/2004 22:00 - 00:00 2.00 CASE P INT1 - PJSM - c/o upper pipe rams to 7 5/8" . - Bring 75/8" casing tools to rig floor. 12/2/2004 00:00 - 00:30 0.50 CASE P INT1 - Test door seals to 1,000 psi for 5 min. - R/D test equip't. 00:30 - 01 :30 1.00 CASE P INT1 - Make dummy run w/ casing hanger on LJ. - R/U to run casing. - Dropped 200T slip segment downhole. 01 :30 - 02:30 1.00 FISH N HMAN INT1 - Discuss options w/ Baker, Schlumberger, & Anchorage. Decision to attempt segment retrieval w/ slickline & magnet. 02:30 - 03:30 1.00 FISH N HMAN INT1 - Wait on slickline unit to arrive from DS 15. - UD casing tools, set bowl protector, P/U & install short bails & 4" elevators. 03:30 - 05:30 2.00 FISH N HMAN INT1 - Prepared rig floor for slickline equip't. - M/U Baker tools - 8" magnet & 3 XO's to 3/4" sucker rod conn. - Spot slickline unit & load tools in pipeshed. 05:30 - 08:00 2.50 FISH N HMAN INT1 - PJSM - R/U slickline unit w/lubricator for pressure control. 08:00 - 14:30 6.50 FISH N HMAN INT1 - RIH w/ magnet - tagged up @ 2831' WLM & slowly POH - No fish. - RIH to 2851' & tagged up - Pushed fish to 2854' & set down @ 2854' x 3. POH - no fish. - RIH to 2854' & tagged fish. Pushed & worked fish to 3092'. POH w/ indication of fish on magnet until 2811'. Lost weight. RIH & tagged up @ 2811 '. Could not work past 2811 '. POH - no fish. - RI H & tagged up @ 2820'. Slowly worked magnet - fish moving downhole. Tagged up @ 3120' - POH w/ good indication of fish on magnet. Lost fish @ 2958'. RIH to 3250' & tag fish. POH w/ good indication of fish & lost fish @ 2932'. RIH & tagged fish @ 3000' & POH to 2932' losing fish @ 2932' x 5. POH w/ Slickline, No Recovery. 14:30 - 15:30 1.00 FISH N HMAN INT1 - C/O slickline assy to LIB. RIH & pushed fish to 3330' in attempt to obtain impression of fish. POH & UD LIB w/ slight impression of fish, nothing conclusive. 15:30 - 17:30 2.00 FISH N HMAN INT1 - M/U grabber tool assy & RIH. Push fish to 3800' & attempt to latch fish. Hole getting sticky - POH - no fish. 17:30 - 18:30 1.00 FISH N HMAN INT1 - PJSM - R/D slickline. 18:30 - 20:30 2.00 BOPSUF P INT1 - PJSM - drain stack, pulled bowl protector & installed test plug. - C/O top pipe rams from 75/8" to 3 1/2" x 6" variables. 20:30 - 21 :00 0.50 BOPSUF P INT1 - PJSM - R/U test equip't. 21 :00 - 00:00 3.00 BOPSUP P INT1 - Test BOPE per BP & AOGCC regs to 250 /3500 psi for 5/ 5 min. Witness of test waived by AOGCC Rep Chuck Scheve. 12/3/2004 00:00 - 01 :00 1.00 BOPSUF P INT1 - R/D BOPE test equip't, B/D choke & kill lines, pulled test plug & installed bowl protector. 01 :00 - 04:00 3.00 FISH N HMAN INT1 - P/U & M/U BHA # 10 for pushing junk to bottom consisting of: 8518" "metal muncher" bladed mill, boot basket, bit sub, oil jars, XO, 3 61/4" DC's, 2 XO's & 12 jts HWDP. 04:00 - 08:30 4.50 FISH N HMAN INT1 - Thaw out kelly hose. - B/O kelly hose @ standpipe gooseneck & thaw ice plug w/ steam hose. P/U & M/U kelly hose. 08:30 - 10:30 2.00 FISH N HMAN INT1 - RIH w/ clean out assy on 4" DP to 2850' & broke circ. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12/3/2004 08:30 - 10:30 2.00 FISH N HMAN INT1 - RIH from 2850' to 3600' & broke circ 3 BPM 500 psi. After pumping 10 bbls pressure increased to 2000 psi. Bled off & attempted to pump - pressure increased to 2500 psi. Bled off pressure, checked surface system - system clear. Drill string plugged off. 10:30 - 12:00 1.50 FISH N HMAN INT1 - Attempted to unplug drill string wlo success. POH to 2800' & attempted to unplug drill string wlo success. 12:00 - 14:00 2.00 FISH N HMAN INT1 - POH wet wI 4" DP to BHA. 14:00 - 15:00 1.00 FISH N HMAN INT1 - BID BHA & cleaned out plugged mill. 15:00 - 16:00 1.00 FISH N HMAN INT1 - M/U BHA for pushing junk to bottom. 16:00 - 17:30 1.50 FISH N HMAN INT1 - RIH wI clean out assy on 4" DP to 3600' filling @ 2850'. 17:30 - 18:00 0.50 FISH N HMAN INT1 - CBU @ 3600'.550 GPM 1300 psi. 18:00 - 21 :30 3.50 FISH N HMAN INT1 - RIH from 3600' @ 1.5 min per stand & tag fish w/20K @ 5687'. Stack 20K x 3, & 30K x 2 in attempt to move fish. P/U 15' & break circ. - Stack 20K x 2 on fish wi pumps on - 650 GPM, 2220 psi - no movement. - Circulate on top of fish wI no wt on mill for 30 min - 700 GPM, 2630 psi - P/U & rotate 10, 20, & 60 RPM wI different wts. on mill from 1 to 15K. On junk Tq 2 to 3K higher than off bottom Tq. P/U wt 135K, SIO wt 105K, Rot wt 117K. - WOM 10K, 10 RPM, pump rate 700 GPM, 2630 psi, Tq 5K. Mill torqued up, fish fell down hole. Worked stand x 2 wI no drag. 21 :30 - 22:30 1.00 FISH N HMAN INT1 - RIH from 5687' to 6632'. 22:30 - 00:00 1.50 FISH N HMAN INT1 - Tag fish @ 6632' w/20K. P/U & stack 50K on fish x 5 - no movement. - Circulate on top of fish wI no wt -700 GPM 2850 psi for 15 min. - Mill on fish w/5K WOM, 10 RPM, off bottom Tq 4K, on bottom Tq 7 to 9K, 700 GPM 2850 psi. - Push fish from 6632' to 6640'. 12/4/2004 00:00 - 01 :00 1.00 FISH N HMAN INT1 - Milled & washed on fish from 6640' to 6880'. WOM 10K, 10 RPM, TQ 7-9K, pump pressure 2160 psi @ 600 GPM. 01 :00 - 03:00 2.00 FISH N HMAN INT1 - At TD stack 50K to 60K wt on fish x 5.600 GPM 2150 psi - Mill new hole from 6880' to 6885'. WOM 5K to 14K, 100 RPM, Tq 7 - 8K, 600 GPM 2180 psi. - Work string from 6885' to 6865' x 10. 03:00 - 05:00 2.00 FISH N HMAN INT1 - Pumped 20 bbllow-vis weighted sweep followed by 20 bbl I hi-vis sweep & CBU x 3.600 GPM 2150 psi 120 RPM. - Monitored well. 05:00 - 06:00 1.00 FISH N HMAN INT1 - Pump lube pill - pump dry job - BID equip't. 06:00 - 06:30 0.50 FISH N HMAN INT1 - POH from 6885' to 6632'. - Pulled tight wI 40K overpull. 06:30 - 13:30 7.00 FISH N HMAN INT1 - Attempted to RIH from 6632' wlo success. Stacked 50K on mill & engaged pumps, 610 GPM 2050 psi. Could not rotate pipe. Continued to work pipe & obtained rotation wI 20 RPM, Tq 5 - 20K. Worked string. - Backreamed out of hole fromm 6632' to 6435' @ 120 RPM, 610 GPM 2000 psi. Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12/4/2004 06:30 - 13:30 7.00 FISH N HMAN INT1 - Hung up @ 6434' - pump rate 610 GPM, 2000 psi. Could not rotate. Worked drill string & jarred up wI 50K overpull x 4. - Obtained rotation & backreamed out of hole dragging fish from 6434' to 5477'. - Lost drag @ 5500'. POH from 5479' to 5380' wI no drag. 13:30 - 15:30 2.00 FISH N HMAN INT1 - BID TD. - POH from 5380' to BHA pulling slowly through 9 5/8" shoe wI no drag. 15:30 - 17:30 2.00 FISH N HMAN INT1 - POH, clean & B/O BHA. 17:30 - 18:30 1.00 FISH N HMAN INT1 - Clear & clean floor. Loaded new BHA tools & brought to rig floor. 18:30 - 19:00 0.50 FISH N HMAN INT1 - Service TD. 19:00 - 19:30 0.50 FISH N HMAN INT1 - Loaded additional collars in pipeshed & brought additional mills to rig floor for current BHA. 19:30 - 21 :30 2.00 FISH N HMAN INT1 - M/U BHA consisting of: 8 1/8" tapered mill, 83/8" string mill, XO, float sub, NM spiral DC, XO, 8 3/8" string mill, XO, NM spiral DC, 8 1/2" string mill, oil jars, NM spiral DC, XO, 3 DC's, 2 XO's & 12 jts 4" HWDP, 21 :30 - 00:00 2.50 FISH N HMAN INT1 - RIH to 5005'. Filled pipe @ 2800'. 12/5/2004 00:00 - 01 :00 1.00 FISH N HMAN INT1 - RIH from 5005' to 5775'. Filled pipe @ 5200'. - No drag while running in hole wI SIO wt 105K. At 5775' picked up stand to check drag on upstroke & tagged junk wI 25K overpull @ 5695'. 01 :00 - 02:30 1.50 FISH N HMAN INT1 - Backream stand from 5775' to 5679 x 3 - 60 RPM, 600 GPM, 2280 psi. - Increase rotary to 100 RPM & backream stand from 5775' to 5679' x 7. Shut off rotary & pumps & work stand - no drag up or down. - Rack back stand & check drag on upstroke from 5679' to 5583', No drag. - RIH to 5871' - P/U from 5871' to 5775' to check for drag. No drag 02:30 - 03:30 1.00 FISH N HMAN INT1 - RIH from 5871' to TD @ 6885' wI no problems. Checked for drag from 6542' to 6446', 6736' to 6639', & from 6885 to 6832'. 03:30 - 05:00 1.50 FISH N HMAN INT1 - Pumped 20 bbllow vis weighted sweep followed by 20 bbl hi-vis sweep & circulate surface to surface & additional B/U. 05:00 - 06:30 1.50 FISH N HMAN INT1 - Monitor well - POH from 6885' to 5200' wI no drag. Monitor well - static. Pump dry job & BID TD. 06:30 - 10:00 3.50 FISH N HMAN INT1 - POH wI 4" DP to BHA - no drag. 10:00 - 12:30 2.50 FISH N HMAN INT1 - B/O & UD BHA. 12:30 - 13:00 0.50 FISH N HMAN INT1 - Cleared & cleaned rig floor. 13:00 - 13:30 0.50 BOPSUF N HMAN INT1 - PJSM - drained stack, pulled bowl protector & installed test plug. 13:30 - 15:00 1.50 BOPSUP N HMAN INT1 - CIO upper rams to 7 5/8". - Tested door seals to 1000 psi. - Pulled test plug. 15:00 - 15:30 0.50 CASE N HMAN INT1 - PJSM for rigging up & running casing. 15:30 - 17:00 1.50 CASE N HMAN INT1 - R/U 7 5/8" casing handling equip't. 17:00 - 20:00 3.00 CASE P INT1 - M/U & run 33 jts. 75/8" 29.7# L-80 STL FJ casing. - Bakerlok connections on pin end of jts 2 & 3. Broke circulation & checked floats - floats holding. M/U to 5200 ftllbs Tq and utilizing Jet Lube Seal Guard thread compound on Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1215/2004 17:00 - 20:00 3.00 CASE P INT1 connections. 20:00 - 21 :00 1.00 CASE N SFAL INT1 - Dropped casing jts between pit complex & pipeshed. Secure area & stand down for safety. Discuss & review incident wI all crew members. 21 :00 - 22:30 1.50 CASE N SFAL INT1 - Reposition casing in yard to facilitate loading ODS portion of pipeshed & load casing. 22:30 - 00:00 1.50 CASE P INT1 - Run 75/8" 29.7# L-80 STL FJ casing to 2112' filling every jt via Frank's fill up tool. 12/6/2004 00:00 - 01 :30 1.50 CASE P INT1 - Run 7 5/8" 29.7# L-80 STL FJ casing to 2839' filling every jt wI Frank's fill up tool. - M/U to 5200 ftllbs Tq. & utilizing Jet Lube Seal Guard thread compound on connections. 01 :30 - 02:00 0.50 CASE P INT1 - CBU x 2 @ 9 5/8" casing shoe. 4 - 5 BPM wI no losses. - 4 BPM 370 psi, 5 BPM 400 psi. - P/U wt 115K, SIO wt 110K. 02:00 - 10:30 8.50 CASE P INT1 - Continue running 75/8" 29.7# STL FJ casing into OH @ 60 sec I jt breaking circulation every 20 jts. Running speed 6 min per jt while breaking circulation. - Wash last jt down @ 5 BPM 640 psi. - Ran a total of 167 jts, 2 19.9' & 2 10' pup jts. RA tags @ 6703', 6346', 6062' & 5940'. 10:30 - 11 :00 0.50 CASE P INT1 - B/O & UD Frank's tool - M/U cement head. 11 :00 - 13:00 2.00 CEMT P INT1 - Staged up pumps - circ & cond mud @ 2 BPM 330 psi, 4 BPM 530 psi & 5 BPM 590 psi. - Reciprocated 5' while circulating. Took 350K to obtain pipe movement - PIU wt 225K, SIO wt 127K after initial movement. - Held PJSM wI Rig Crew, Cementers, Truck Drivers, Mud Eng, Tool Pusher & Co. Rep while circulating. 13:00 - 15:00 2.00 CEMT P INT1 - Pumped 5 bbls fresh water & tested lines to 4,000 psi. Pumped 20 bbls CW 100 @ 4 BPM 600 psi followed by 30 bbls 10.2 ppg Mud Push @ 4.5 BPM 650 psi. Dropped bottom plug & pumped 49 bbls ( 229 sx ) 15.8 ppg Class G cement. Dropped top plug and pumped 10 bbls fresh water via Cementers @ 5 BPM 290 psi. - Switched over to rig pump & displaced wI 301.8 bbls Seawater at following rates: Pumped Rate Pressure 50 bbls 5bpm 300 psi 100 bbls 5bpm 400 psi 150 bbls 5 bpm 450 psi 200 bbls 5bpm 475 psi 250 bbls 5 bpm 550 psi Slowed Rate to 3 bpm wI 292 bbls pumped. Bumped plug wI 1,900 psi & held pressure for 3 min. - Bled off pressure & checked floats - floats held. - CIP 1500 hrs. 15:00 - 16:30 1.50 CEMT P INT1 - RID cement equip't & cleared floor. - CIO bails & elevators. 16:30 - 17:00 0.50 CASE P INn - PJSM - Installed 9 5/8" x 7 5/8" packoff & tested to 5,000 psi for 10 min. Good test. 17:00 - 19:30 2.50 BOPSUF P INT1 - PJSM - Installed test plug & CIO upper rams from 75/8" to 3 1/2" x 6" variables. - R/U test equip't & tested door seals to 1,000 psi - RID test Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1216/2004 17:00 - 19:30 2.50 BOPSUF P INT1 equip't & pulled test plug. 19:30 - 20:00 0.50 CASE P INT1 - Serviced TD. 20:00 - 21 :00 1.00 DRILL P PROD1 - Load BHA tools on tloor. - M/U 63/4" BHA - 6 3/4" PDC bit, mud motor dialed in to 1.5 deg bend & 6 3/4" stab. 21 :00 - 00:00 3.00 DRILL N DPRB PROD1 - RIH & tag up @ 27.7' wI PDC bit. POH & inspect bit. - RIH & tag up @ 27.7' - Apply 5K wt to bit - no go. Apply 5K wt to bit @ 5 RPM - no go. - Change setting on motor to 0 deg bend & RIH - no go - POH & remove bit. RIH wI motor & 6 5/8" sleeve on motor & able to RIH to 31' wlo tagging up. 1217/2004 00:00 - 01 :00 1.00 DRILL N DPRB PROD1 Attempt to RIH wI two different PDC bits & tagged up @ 27.7'. 01 :00 - 02:30 1.50 DRILL P PROD1 PJSM - Line up to OA & test line to 3000 psi. Pumped 50 bbls mud down annulus @ 1 BPM. SPM Pressure Total stks 12 630 120 12 610 180 12 660 240 13 720 300 13 720 360 13 710 420 13 700 480 13 700 540 13 700 588 02:30 - 03:00 0.50 DRILL N DPRB PROD1 UD drilling BHA. 03:00 - 04:00 1.00 DRILL N DPRB PROD1 MU 6-3/4" string mill with a stabilizer and a 6-1/4" DC. 04:00 - 04:30 0.50 FISH N DPRB PROD1 Mill through obstruction @ 27.7'. Milled for - 6" & cleaned up area. Ran mill wlo rotatating to 167' to ensure clear below. 04:30 - 05:00 0.50 DRILL N DPRB PROD1 UD milling BHA. 05:00 - 07:30 2.50 DRILL P PROD1 RU test equipment. Close blind rams and test csg to 3500 psi for 30 minutes. Bleed pressure, open rams and RD test equipment. 07:30 - 10:30 3.00 DRILL P PROD1 PU and MU 6-3/4" directional BHA #14 10:30 - 14:30 4.00 DRILL P PROD1 RIH to 2250' with 6-3/4" directional BHA. Shallow test MWD @ 685'. SymOps: PJSM. RU Little Red to 7-518" X 9-5/8" annulus. Test lines to 3000 psi. Inject 45 bbls dead crude to freeze protect. IPR 2 bpm @ 1500 psi FPR 2 bpm @ 1500 psi. Shut in with 950 psi, pressure bled to 250 psi by midnight 14:30 - 16:00 1.50 DRILL P PROD1 Change out saver sub and service top drive. 16:00 - 21 :00 5.00 DRILL P PROD1 Continue RIH from 2250' to 6050' picking up DP from pipe shed 21 :00 - 22:00 1.00 DRILL P PROD1 Cut and slip 60' of drill line. 22:00 - 22:30 0.50 DRILL P PROD1 Circulate a drill string volume to ensure DP free of obstructions. 22:30 - 23:30 1.00 DRILL P PROD1 RIH from 6050' to 6625'. MU top drive and wash last stand down down, tagged up on cement stringers @ 6740' 23:30 - 00:00 0.50 DRILL P PROD1 Wash and ream down from 6740' cleaning up cement stringers. 12/8/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Continue washing and reaming down to 6781' cleaning up Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/19/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 1218/2004 00:00 - 01 :30 1.50 DRILL P PROD1 cement stringers to the float collar. 01 :30 - 02:00 0.50 DRILL P PROD1 PJSM with Veco and all rig personnel on displacing to MOBM. 02:00 - 03:00 1.00 DRILL P PROD1 Pump 20 bbl L VT spacer followed by MOBM to displace well to 9.2 ppg MOBM, 215 gpm @ 1000 psi 03:00 - 05:00 2.00 DRILL P PROD1 Circulate surface to surface X 2 to shear and warm MOBM. 330 gpm @ 2500 psi. 05:00 - 08:00 3.00 DRILL P PROD1 Drill shoe track cement from 6781' to 6870'. Clean out 8-3/4" rathole from 6870' to 6885' and drill 23' of new hole to 6908' WOB = 5 klbs RPM Surf= 50, DH = 225 GPM = 285 @ 2100 psi on Btm Torque = 3k FtLbs 08:00 - 09:30 1.50 DRILL P PROD1 PJSM. Break off stand and pull bit inside 7-5/8" csg. Perform 10.5 ppg EMW FIT, 411 psi surf pressure at 5265' TVD with 9.0 ppg mud in the hole. Baseline ECD = 9.89 ppg 09:30 - 14:00 4.50 DRILL P PROD1 Directional drill from 6908' to 7197', sliding as required to maintain inclination and azimuth. WOB = 3-5 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 2900 psi on Btm, 2570 psi off Btm P/U 125k SIO 97k ROT 11 Ok Backream each stand at drilling rate, reducing pump rate on down stroke. Calculated ECD = 10.09 ppg Actual ECD = 10.45 ppg 14:00 - 15:00 1.00 DRILL P PROD1 POH to 7033' and RIH picking up 30' surveys to 7197 15:00 - 00:00 9.00 DRILL P PROD1 Directional drill from 7197' to 7869', sliding as required to maintain inclination and azimuth. WOB = 3-5 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3100 psi on Btm, 2800 psi off Btm P/U 125k SIO 90k ROT 11 Ok Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30' Calculated ECD = 10.10 ppg Actual ECD = 10.47 ppg ART last 24 hrs. =2.23 hrs. AST last 24 hrs. = 4.33 hrs. Total drilling hours = 6.56 hrs 12/9/2004 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 7869' to 9851', sliding as required to maintain inclination within constraints provided by rig site geologist to maximize reservoir contact. Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1219/2004 00:00 - 00:00 24.00 DRILL P PROD1 WOB = 4-7 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3320 psi on Btm, 3120 psi off Btm Torque = 7k FtLbs on Btm, 6k FtLbs of Btm P/U 135k S/O 85k ROT 11 Ok Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Circulate lo-vis and weighted sweeps as required to ensure clean hole conditions. Calculated ECD = 10.23 ppg Actual ECD = 10.47 ppg ART last 24 hrs. = 5.92 hrs. AST last 24 hrs. = 2.93 hrs. Total drilling hours = 8.85 hrs 12/10/2004 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 9851' to 11708', sliding as required to maintain inclination within constraints provided by rig site geologist to maximize reservoir contact. WOB = 4-11 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3550 psi on Btm, 3200 psi off Btm Torque = 7-8k FtLbs on Btm, 6-7k FtLbs of Btm P/U 132k SIO 75k ROT 107k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Circulate sweeps as required to ensure clean hole conditions. Calculated ECD = 10.82 ppg Actual ECD = 11.02 ppg ART last 24 hrs. = 3.93 hrs. AST last 24 hrs. = 4.50 hrs. Total drilling hours = 8.43 hrs 12/11/2004 00:00 - 05:00 5.00 DRILL P PROD1 Directional drill from 11708', to TD of lateral #1 at 12190' sliding as required to maintain inclination within constraints provided by rig site geologist to maximize reservoir contact. WOB = 3-6 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3730 psi on Btm, 3240 psi off Btm Torque = 8k FtLbs on Btm, 7.5k FtLbs of Btm P/U 144k SIO 70k ROT 109k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.91 ppg Actual ECD = 11.30 ppg ART last 24 hrs. = 1.10 hrs. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11 /1 9/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 12/11/2004 00:00 - 05:00 5.00 DRILL P PROD1 AST last 24 hrs. = 0.90 hrs. Total drilling hours = 2.00 hrs 05:00 - 07:30 2.50 DRILL P PROD1 CBU X 2, to circulate and condition hole. RPM = 80 330 gpm @ 3200 psi. Intial ECD = 11.25 ppg Final ECD = 11.10 ppg Calculated ECD = 10.91 ppg 07:30 - 09:30 2.00 DRILL P PROD1 POH for wiper trip to csg shoe from 12190' to 11703', 35 klbs drag and swabbing 09:30 - 17:00 7.50 DRILL P PROD1 MU top drive and backream out from 11703' to 6813'. RPM = 80 GPM = 330 @ 3000 psi Torque = 8-10k FtLbs 17:00 - 18:00 1.00 DRILL P PROD1 CBU X 2 at the 7-5/8" csg shoe. 18:00 - 19:00 1.00 DRILL P PROD1 Service top drive, blocks, crown, drawworks and iron roughneck. 19:00 - 22:00 3.00 DRILL P PROD1 RIH to 12096' filling DP every 20 stands. Work through tight spots from 11710' to 12096' 22:00 - 23:00 1.00 DRILL P PROD1 MU top drive and wash last stand to bottom at 12190' 23:00 - 00:00 1.00 DRILL P PROD1 Pump a 20 bbllo-vis sweep followed by a 20 bbl weighted sweep. RPM = 80 330 gpm @ 3300 psi. 12/12/2004 00:00 - 02:00 2.00 DRILL P PROD1 Continue circulating BU X 3 to clean and condition hole. RPM = 80 330 gpm @ 3780 psi. Intial ECD = 11.45 ppg Final ECD = 11.19 ppg Calculated ECD = 11.17 ppg SymOps: PJSM. Transfer MOBM from pit module to 400 bbl upright tanks. 02:00 - 02:30 0.50 DRILL P PROD1 PJSM with MI, Veco and all rig personnel on displacing well to SFMOBM. 02:30 - 04:00 1.50 DRILL P PROD1 Displace well to Solids Free MOBM. rate 285 gpm @ 2970 psi 04:00 - 10:30 6.50 DRILL P PROD1 Monitor well - static. POH from 12190' to 6520' to run 4-1/2" liner. Worked through 7-5/8" csg shoe at 6870'. Recorded PI U and S I 0 Weights every 1,000'. Circulated bottoms up at csg shoe, 330 gpm 2,500 psi, RPM 60. 10:30 - 13:30 3.00 DRILL P PROD1 MAD pass from 6520' to 5900' to verify placement of RA tags in 7-5/8" csg. 13:30 - 17:00 3.50 DRILL P PROD1 Continue POH from 5951 to 208', Recorded PI U and S I 0 Weights every 1,000'. 17:00 - 17:30 0.50 DRILL P PROD1 PJSM with Anadrill and all rig personnel on pulling RA sources and laying down the BHA. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12112/2004 17:30 - 20:00 2.50 DRILL P PROD1 20:00 - 21 :00 1.00 DRILL P PROD1 21 :00 - 21 :30 0.50 CASE P PROD1 21 :30 - 22:00 0.50 CASE P PROD1 22:00 - 00:00 2.00 CASE P PROD1 12/13/2004 00:00 - 05:00 5.00 CASE P PROD1 05:00 - 06:00 1.00 CASE PROD1 06:00 - 07:30 1.50 CASE P PROD1 07:30 - 08:00 0.50 CASE P PROD1 08:00 - 12:00 4.00 CASE P PROD1 12:00 - 13:30 1.50 CASE P PROD1 13:30 - 16:30 3.00 CASE P PROD1 16:30 - 17:00 0.50 CASE P PROD1 17:00 - 17:30 0.50 CASE P PROD1 17:30 - 18:30 1.00 CASE P PROD1 18:30 - 22:00 3.50 STWHIP P WEXIT 22:00 - 00:00 2.00 STWHIP P WEXIT 12/14/2004 00:00 - 05:30 5.50 STWHIP P WEXIT 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30 - 09:00 2.50 STWHIP P WEXIT 09:00 - 15:00 6.00 STWHIP P WEXIT LD BHA #14, Clear floor and remove RA sources. Clean and clear rig floor. Rig up to run 4-1/2" liner PJSM with Baker and all rig personnel on picking up and running 4-1/2",12.6#, IBT-M, L-80 liner. PU and RUN 4-1/2",12.6#, L-80, IBT-M slotted liner. Continue PU and RUN 4-1/2", 12.6#, L-80, IBT-M slotted liner. Ran 127 jts slotted liner, 10 jts solid liner, average MU torque 2200 FtLbs. A free floating 5-3/4" centralizer was run on each joint, except the shoe joint. MU seal bore extension, ZXP liner top packer and liner hanger with liner running tool. RD 4-1/2" tbg equipment. RIH with 4-1/2" liner on DP to 7-518" csg shoe @ 6870. Circulate 1-1/2 X the string volume. 6 bpm @ 880 psi Continue RIH with 4-1/2" liner on DP, break circulation every 15 stands. Record PIU and SIO weights every 500'. MU top drive and break circulation. Drop setting ball. RIH and tag up at 12190'. PU and space out liner top at 6446, shoe at 12184'. Stage up pump and pump ball on seat, 2 bpm @ 270 psi. Increase pressure to 2000 psi to set liner hanger, stack 20k Ibs on liner to verify hanger set. Increase pressure to 4000 psi to set ZXP packer. Bled down pressure and closed annular, tested packer to 1500 psi for 5 minutes. Monitor well- static. POH with 4" DP. Break out and LD liner running tool. Clean and clear rig floor. Service top drive, blocks and iron roughneck. MU whipstock assembly. PU and Orient MWD. PU 12 jts of 4-3/4" DC's and 24 jts of 4" HWDP. RIH wI Whipstock Assembly on 4" DP to 6,399'. MU top drive and orient whipstock. RIH and set whipstock anchor and dummy seal assembly at 6,457'. Whipstock slide oriented 14 deg left of highside. Set down whipstock trip anchor wI 20,000# slackoff, stacked addtional1 0,000# on anchor to ensure set. PU wI 10,000# overpull to check anchor set. Stacked 40,000# on mill and sheared free from whipstock. PU to neutral weight and rotated drill string to ensure mills sheared free from whipstock slide. Top of whipstock at 6,397'. Held PJSM. Displaced well bore from SFMOBM to MOBM. Pump rate 3 bpm @ 1,200 psi. Total displacement 240 bbls. Took returns of SFMOBM back to pit #3 and hauled to MI plant for reconditioning. Circulated mud system one full surface to surface to condition mud. Mill window from 6397' to 6409'. Continue milling and dressing window to 6423'. WOM = 5 klbs RPM = 100-110 GPM = 285 @ 1910 psi Torque = 5-8k FtLbs P/U 120k SIO 11 Ok ROT 105k 100 Ibs of metal recovered Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12114/2004 15:00 - 16:30 1.50 STWHIP P WEXIT Circulate 35 bbl hi-vis sweep around to clean metal from hole. 16:30 - 18:30 2.00 STWHIP P WEXIT Monitor well - static. Slug DP and POH with milling assembly. 18:30 - 20:30 2.00 STWHIP P WEXIT Stand back HWDP and DC's. LD milling BHA. 20:30 - 22:00 1.50 BOPSUF P WEXIT Flush and drain BOP stack. Pull wear bushing and install test plug 22:00 - 22:30 0.50 BOPSUF P WEXIT RU BOP test equipment fill stack with water. 22:30 - 00:00 1.50 BOPSUF P WEXIT Test BOPE to 3500 psi 1250 psi, test annular to 2500 psi 1250 psi for 5 minutes each. Witness of BOP test waived by John Spaulding with AOGCC. 12/15/2004 00:00 - 04:00 4.00 BOPSUF P WEXIT Continue testing BOPE to 3500 psi 1250 psi, test annular to 3500 psi 1250 psi for 5 minutes each. Witness of BOP test waived by John Spaulding with AOGCC. 04:00 - 04:30 0.50 BOPSUF P WEXIT RD test equipment, pull test plug. Drain water from stack to cuttings box. Install wear bushing 04:30 - 05:00 0.50 STWHIP P WEXIT PJSM with Anadrill and all rig personnel on Picking up and loading RA sources in BHA. 05:00 - 09:00 4.00 STWHIP P WEXIT PU and MU 6-3/4" directional BHA with Hycalog DS146X. Load RA sources and RIH. 09:00 - 13:00 4.00 STWHIP P WEXIT RIH with BHA #16 on DP. MU top drive and shallow test MWD at 1000'. Break circ every 20 stands on trip in. 13:00 - 14:30 1.50 STCTPL P WEXIT Log down across 2 RA markers and confirm depths at 5933' and 6055' MD DP measurement - OK. Obtain benchmark ECD readings with PWD at 10.08 ppg @ 325 gpm and validate ECD model. 14:30 - 15:30 1.00 STWHIP P WEXIT Cut drilling line. 15:30 - 16:00 0.50 STWHIP P WEXIT MU top drive, orient tool 14 degrees right and RIH passing through window at 6397' without difficulty. Stage up pump and wash down to TD at 6423'. 16:00 - 00:00 8.00 DRILL P PROD2 Directional drill from 6423', to 6906' as per directional plan. WOB = 5-8 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 2820 psi on Btm, 2440 psi off Btm Torque = 5-5.5k FtLbs on Btm, 4-5k FtLbs off Btm PIU 120k SIO 95k ROT 11 Ok Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.10 ppg Actual ECD = 10.23 ppg ART last 24 hrs. = 1.48 hrs. AST last 24 hrs. = 1.63 hrs. Total drilling hours = 3.11 hrs 12/16/2004 00:00 - 00:30 0.50 DRILL P PROD2 Directional drill from 6906', to 7003' as per plan. WOB = 5-10 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 2600 psi on Btm, 2430 psi off Btm Torque = 5-5.5k FtLbs on Btm, 4-5k FtLbs off Btm PIU 120k SIO 95k ROT 11 Ok Printed: 2/7/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12116/2004 00:00 - 00:30 0.50 DRILL P PROD2 Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.13 ppg Actual ECD = 10.40 ppg 00:30 - 01 :30 1.00 DRILL N RREP PROD2 Repair top drive upper kelly valve actuator. 01 :30 - 07:00 5.50 DRILL P PROD2 Directional drill from 7003', to 7292' as per directional plan. WOB = 4-7 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 2550 psi on Btm, 2410 psi off Btm Torque = 5-6k FtLbs on Btm, 5k FtLbs off Btm P/U 120k S/O 95k ROT 11 Ok Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Crossed fault at 6895' MD. Calculated ECD = 10.19 ppg Actual ECD = 10.20 ppg 07:00 - 09:00 2.00 DRILL N DPRB PROD2 Saw sudden increase in pump pressure of -700 psi and ECD jump to 10.45 ppg shortly after making a connection. Suspect cuttings avalanching uphole (in casing). Drilling in OBc shale from 7050' MD. Backream out from 7292 - 7090' to clean up hole. Getting back abundant amount of shale cuttings approx 1/8" - 1/4" cubes (angular). Continue slow backreaming until hole cleaned up and pressure & ECD returned to normal. No mud losses noted. 09:00 - 09:30 0.50 DRILL N DPRB PROD2 RIH to bottom - no problems. 09:30 - 13:00 3.50 DRILL P PROD2 Directional drill from 7292', to 7420' as per plan. WOB = 5-10 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 2600 psi on Btm, 2430 psi off Btm Torque = 5-5.5k FtLbs on Btm, 4-5k FtLbs off Btm PIU 120k SIO 95k ROT 11 Ok Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.13 ppg Actual ECD = 10.40 ppg 13:00 - 15:00 2.00 DRILL N DFAL PROD2 Cuirculate while attempting to reestablish communication with MWD/LWD tools. 15:00 - 16:30 1.50 DRILL N DFAL PROD2 Backream from 7420' to 7100' to clean hole prior to trip for MWD. 16:30 - 18:00 1.50 DRILL P PROD2 Communication with MWD/LWD re-established. Circulate hole clean and RIH to bottom at 7420'. 18:00 - 23:00 5.00 DRILL P PROD2 Directional drill from 7420', to 7920' as per plan. WOB = 5-9 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3010 psi on Btm, 2860 psi off Btm Torque = 6k FtLbs on Btm, 5k FtLbs off Btm Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12116/2004 18:00 - 23:00 5.00 DRILL P PROD2 PIU 120k SIO 93k ROT 105k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.29 ppg Actual ECD = 10.31 ppg 23:00 - 00:00 1.00 DRILL P PROD2 Saw pressure and ECD increase with corresponding increase in 1/8" to 1/4" angular to blocky cutting sized shale pieces across shaker. Circulated weighted sweep surface to surface. 12/17/2004 00:00 - 00:30 0.50 DRILL P PROD2 Continue to circulate weighted sweep out of hole. Sweep brought an increase in cuttings volume across shaker, mostly 1/4" to 1/8" angular to blocky shale and some fine sands. 00:30 - 02:30 2.00 DRILL P PROD2 Directional drill from 7920' to 8059' sliding as required to build into the OBb as per plan. WOB = 9-10 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3140 psi on Btm, 3040 psi off Btm Torque = 5k FtLbs off Btm PIU 123k SIO 93k ROT 105k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Added 1 drum of HRP to mud system to increase YP and gel strength. Calculated ECD = 10.31 ppg Actual ECD = 10.71 ppg 02:30 - 03:30 1.00 DRILL P PROD2 Circulate for ECD management, circulating HPR through system. 03:30 - 07:00 3.50 DRILL P PROD2 Directional drill from 8059' to 8347' sliding as required to maintain OBb contact as per plan. WOB = 6-7 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3200 psi on Btm, 2970 psi off Btm Torque = 5.5k FtLbs on Btm, 5k FtLbs off Btm P/U 122k SIO 93k ROT 106k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.30 ppg Actual ECD = 10.78 ppg 07:00 - 07:30 0.50 DRILL P PROD2 Circulate for ECD management. 07:30 - 12:00 4.50 DRILL P PROD2 Continue drilling ahead to 8636' MD. Switched from #2 to #1 mud pump. MWD quit working shortly after switching pumps. 12:00 - 13:30 1.50 DRILL P PROD2 Circ and pump out of hole 5 stands to try and clear MWD - OK. RIH to bottom. 13:30 - 00:00 10.50 DRILL P PROD2 Directional drill from 8636' to 9400' sliding as required to maintain OBb contact as per plan. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/19/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 12117/2004 13:30 - 00:00 10.50 DRILL P PROD2 WOB = 6-8 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3400 psi on Btm, 3100 psi off Btm Torque = 8k FtLbs on Btm, 6k FtLbs off Btm P/U 125k SIO 80k ROT 1 OOk Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.76 ppg Actual ECD = 11.11 ppg ART last 24 hrs. = 2.88 hrs. AST last 24 hrs. = 4.19 hrs. Total drilling hours = 7.07 hrs 12/18/2004 00:00 - 08:00 8.00 DRILL P PROD2 Directional drill from 9400' to 10143' sliding as required to maintain OBb contact as per plan. WOB = 3-4 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3750 psi on Btm, 3440 psi off Btm Torque = 6-7k FtLbs on Btm, 6k FtLbs off Btm PIU 135k SIO 80k ROT 115k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Circulate 15bbllo-vis sweep around at 9906'. Slide one full stand to get top drive down to rig floor for troubleshooting. Calculated ECD = 10.76 ppg Actual ECD = 11.18 ppg 08:00 - 11 :00 3.00 DRILL N RREP PROD2 After making a slide and connection, top drive would not rotate or back out of connection. Check out top drive - nothing conclusive seen but possibly a bad encoder that controls TD rotation. 11 :00 - 14:30 3.50 DRILL N RREP PROD2 Get TD connection broken and back out with rotary table. POH to window for top drive repairs - also need to replace blower fan for motors in TD that failed previously. POH to window - no pumping or backreaming possible. Work thru tight spots at 9617',9554-44',9420',9340',9175', 9150-40'. Overpulls to 25 klbs. 14:30 - 21 :30 7.00 DRILL N RREP PROD2 Repair top drive. Replace encoder and purge moisture from upper kelly valve airlines. Blow moter has failed, no spare on Slope but will be able to drill ahead unitl new motor is available. 21 :30 - 22:30 1.00 DRILL N RREP PROD2 RIH to 7956' 22:30 - 23:30 1.00 DRILL N RREP PROD2 MU top drive, stage up pumps and break circulation. TD made up on connection erratically. Top drive saver sub threads have been stripped from pin when making up the stand. Appears to be caused by improper hook-up of new encoder that caused the connection to overtorque. 23:30 - 00:00 0.50 DRILL N RREP PROD2 LD damaged joint of 4" DP. POH to window to change top drive Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12/18/2004 23:30 - 00:00 0.50 DRILL N RREP PROD2 saver sub. 12/19/2004 00:00 - 01 :00 1.00 DRILL N RREP PROD2 Continue POH to change out top drive saver sub. 01 :00 - 02:30 1.50 DRILL N RREP PROD2 Change out top drive saver sub. 02:30 - 04:30 2.00 DRILL N RREP PROD2 RI H to 10132', make up top drive and break circulation at 8246'. 04:30 - 05:00 0.50 DRILL N RREP PROD2 Wash last stand to bottom at 10143' 05:00 - 00:00 19.00 DRILL P PROD2 Directional drill from 10143' to 11656', sliding as required to maintain OBb contact as per plan. WOB = 4-5 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3750 psi on Btm, 3440 psi off Btm Torque = 6-7k FtLbs on Btm, 6k FtLbs off Btm P/U 135k SIO 80k ROT 113k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.76 ppg Actual ECD = 11.18 ppg ART last 24 hrs. = 3.25 hrs. AST last 24 hrs. = 5.26 hrs. Total drilling hours = 8.51 hrs 12/20/2004 00:00 - 05:30 5.50 DRILL P PROD2 Directional drill from 11656' to 12160', sliding as required to maintain OBb contact as per plan. WOB = 4-5 klbs RPM Surf= 80, DH = 260 GPM = 330 @ 3640 psi on Btm, 3410 psi off Btm Torque = 7-8k FtLbs on Btm, 7k FtLbs off Btm P/U 147k SIO 65k ROT 120k Backream each stand at drilling rate, reducing pump rate on down stroke. Survey every 30'. Calculated ECD = 10.85 ppg Actual ECD = 11.02 ppg 05:30 - 07:00 1.50 DRILL P PROD2 Circulate a 20 bbllo-vis sweep followed by a 20 bbl weighted sweep surface to surface. RPM = 80 330 gpm @ 3300 psi. 07:00 - 14:00 7.00 DRILL P PROD2 MU top drive and backream from 12160' to 10050'. Stands 2 & 3 took significant amount of backreaming - pressure increases but no real increase in ECD as if reaming undergauge hole rather than moving cuttings beds. Continue backreaming - became much better above 11300'. RPM = 95 GPM = 330 @ 3000 psi Torque = 8-10k FtLbs 14:00 - 15:00 1.00 DRILL P PROD2 CBU at 10050' - 330 gpm & 95 rpm. Circ until shakers cleaned Printed: 2/7/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12120/2004 14:00 - 15:00 1.00 DRILL P PROD2 up. Pull 3 stds dry - no problems, hole clean. 15:00 - 17:00 2.00 DRILL P PROD2 RIH to bottom. 17:00 - 22:00 5.00 DRILL P PROD2 Circulate BU X 3 to clean and condition hole. RPM = 95 330 gpm @ 3350 psi. Intial ECD = 10.50 ppg Final ECD = 10.26 ppg Calculated ECD = 10.86 ppg SymOps: PJSM. Transfer MOBM from pit module to 400 bbl upright tanks. 22:00 - 22:30 0.50 DRILL P PROD2 PJSM with MI, Veco and all rig personnel on displacing well to SFMOBM. 22:30 - 00:00 1.50 DRILL P PROD2 Displace well to Solids Free MOBM. rate 145 gpm @ 1560 psi 12/21/2004 00:00 - 01 :00 1.00 DRILL P PROD2 Continue displacing well to Solids Free MOBM. rate 145 gpm @ 1560 psi 01 :00 - 01 :30 0.50 DRILL P PROD2 Monitor well - static. Take slow pump rates. Blow down top drive. 01 :30 - 05:00 3.50 DRILL P PROD2 POH from 12160 to the window at 6397'. No problems or tight spots 05:00 - 06:00 1.00 DRILL P PROD2 Service top drive, blocks, crown and drawworks. Change oil in top drive. 06:00 - 07:00 1.00 DRILL N RREP PROD2 Finish changing oil in top drive. 07:00 - 10:00 3.00 DRILL P PROD2 POH to BHA 10:00 - 12:30 2.50 DRILL P PROD2 PJSM. Handle BHA. Remove nuclear source. LD LWD, MWD, motor & bit DSX146H (RR3). 12:30 - 13:00 0.50 DRILL P PROD2 Clear & clean rig floor. 13:00 - 13:45 0.75 CASE P PROD2 RU to run 4.5" slotted liner. 13:45 - 14:00 0.25 CASE P PROD2 PJSM for running liner. 14:00 - 20:00 6.00 CASE P PROD2 Run 4.5" IBT-M slotted liner in OBb lateral per running order. MU 4 jts solid liner, swell packer,S jts slotted liner and aluminium billet liner top. Depth in P/U wt SIO wt 1040' 49K 50K 2082' 58K 62K 3115' 70K 72K 4155' 81K 79K 4580' 85K 80K 20:00 - 00:00 4.00 CASE P PROD2 Run 4 1/2" slotted liner in OBb lateral on 4" DP. Depth in P/U wt SIO wt 5553' 97K 90K 6510' 109K 94K 7470' 115K 92K 8430' 122K 91K 12/22/2004 00:00 - 02:30 2.50 CASE P PROD2 - RIH w/4 1/2" slotted liner on 4" DP to TD @ 12160'. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12/22/2004 00:00 - 02:30 2.50 CASE P PROD2 Depth in PIU wt SIO wt 9387' 130K 82K 9674' 137K 85K 9950' 140K 87K 1 0230' 147K 93K 10415' 154K 92K 10605' 149K 93K 11080' 160K 87K 11560' 167K 83K 12035' 167K 80K 12160' 172K 81K 02:30 - 03:00 0.50 CASE P PROD2 - Tag bottom @ 12160' w/5K. P/U off bottom to break over pt @ 172K & tag bottom w/1 OK. Establish circulation @ 100 GPM 960 psi & pick up string. Up wt 135K - shut down pump & continue picking up string. String wt indicates off of liner. 03:00 - 07:00 4.00 CASE P PROD2 - POH wI 4" DP & UD aluminum billet running spear. 07:00 - 07:30 0.50 CASE P PROD2 - Clear & clean rig floor. 07:30 - 08:00 0.50 STKOH P WEXIT - PJSM for P/U BHA. 08:00 - 10:30 2.50 STKOH P WEXIT - P/U & M/U BHA - 6 3/4" DSX 146 PDC bit, XP motor wI 1.5 deg bend, bypass sub, NM stab, NM flex lead collar, MWD, PWD, ADN, 2 NM flex DC's, XO, & jars. 10:30 - 14:00 3.50 STKOH P WEXIT - RIH from 209' to 6376' filling every 25 stands. - Shallow test MWD @ 1165' - 330 GPM, 1700 psi. 14:00 - 15:00 1.00 STKOH P WEXIT - PJSM - slip & cut drilling line. 15:00 - 18:00 3.00 STKOH P WEXIT - PJSM - RIU & transfer MOBM from upright tanks & displace well from solids free MOBM to MOBM. 330 GPM, 2350 psi, 75 RPM & reciprocating. - Establish clean hole ECD's at 6376' as follows: GPM RPM Pump Pressure ECD 280 0 1655 9.84 280 60 1655 9.92 330 0 2350 10.02 330 60 2350 10.05 18:00 - 20:00 2.00 STKOH P WEXIT - RIH to 6526' - Wash from 6526' to top of billet @ 7581' DPM. 70 GPM 300 psi 20 RPM. 20:00 - 22:00 2.00 STKOH P WEXIT - Trench from 7574' to 7581' @ 330 GPM 2800 psi. 22:00 - 00:00 2.00 STKOH P WEXIT - Time drill @ 2 FPH for 2' & 4 FPH for 4' to sidetrack off of billet @ 330 GPM 2800 psi. - Fine granules of aluminum seen @ shakers on B/U. 12/23/2004 00:00 - 02:00 2.00 DRILL P PROD3 - Time drill @ 4 FPH for 4' & 12 FPH for 10'. Sidetrack off of aluminum billet successful. PU above billet and make a pass by the billet - pumps on. OK. - 100% slide @ 330 GPM 2820 psi 02:00 - 12:00 10.00 DRILL P PROD3 - Drill directionally in 6 3/4" hole from 7601' to 8250' backreaming each stand at full drilling rate & reducing pump rate to 75% on downstroke. - WOB 6K, 330 GPM, PP off bottom 2850 psi, on bottom 3150 Printed: 2/7/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12/23/2004 02:00 - 12:00 10.00 DRILL P PROD3 psi, 80 RPM, Tq on bottom 7K, Tq off bottom 6K. - P/U wt 125K, SIO wt 93K, Rot wt 105K. - Calculated ECD 10.36, actual ECD 10.63. AST 2.98 hrs, ART 1.18 hrs, ADT 4.16 hrs. 12:00 - 00:00 12.00 DRILL P PROD3 - Drill directionally in 6 3/4" hole from 8250' to 9493' backreaming each stand at full drilling rate & reducing pump rate to 75% on downstroke. - WOB 5-8K, 330 GPM, PP off bottom 2830 psi, on bottom 3250 psi, 80 RPM, Tq on bottom 8K, Tq off bottom 7K. - P/U wt 130K, S/O wt 75K, Rot wt 107K. - Calculated ECD 10.65, actual ECD 11.0. - AST 2.43 hrs, ART 2.72 hrs, ADT 5.15 hrs. 12/24/2004 00:00 - 12:00 12.00 DRILL P PROD3 - Drill directionally in 6 3/4" hole from 9493' to 10526' backreaming each stand at full drilling rate and reducing pump rate to 75% on downstroke. - WOB 5-8K, 330 GPM, PP off bottom 3200 psi, on bottom 3500 psi, 80 RPM, Tq on bottom 8K, Tq off bottom 7K. - P/U wt 145K, SIO wt 77K, Rot wt 115K. - Calculated ECD 10.79, actual ECD 10.96. - AST 2.69 hrs, ART 2.36 hrs, ADT 5.05 hrs. 12:00 - 00:00 12.00 DRILL P PROD3 - Drill directionally in 6 3/4" hole from 10526' to 11437' backreaming each stand at full drilling rate and reducing pump rate to 75% on downstroke. -WOB 5-8K, 330 GPM, PP off bottom 3250 psi, on bottom 3600 psi, 80 RPM, Tq on bottom 9K, Tq off bottom 8K. - P/U wt 154K, SIO wt 65K, Rot wt 115K. - Calculated ECD 10.49, actual ECD 10.76. - AST 2.43 hrs, ART 2.85 hrs, ADT 5.28 hrs. 12/25/2004 00:00 - 06:30 6.50 DRILL P PROD3 - Drill directional in 6 3/4" hole from 11437' to TD @ 12043' MD. Backream each stand at full drilling rate & reduce pump rate to 75% on downstroke. - WOB 5-8K, PP off bottom 3260 psi, on bottom 3700 psi, 80 RPM, Tq on bottom 10K, off bottom 9K. - P/U wt 165K, SIO wt 60K, Rot wt 115K. - Calculated ECD 10.71, actual ECD 10.89 - AST 1.12 hrs, ART 2.07 hrs, ADT 3.19 hrs. 06:30 - 10:00 3.50 DRILL P PROD3 - Circ lo-vis sweep surface to surface. Circ until actual ECD was 10.78 vs 10.74 calculated. 10:00 - 10:30 0.50 DRILL P PROD3 - Monitor well while blowing down TD. 10:30 - 17:30 7.00 DRILL P PROD3 - POH for check trip to window. Hole condition v. good - no pump or backreaming required. - Pump out past billet and saw 10k overpulls - stabilizer on ADN. Nothing when bit went across billet. Orient 120L and stop Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12125/2004 10:30 - 17:30 7.00 DRILL P PROD3 pump. Run in below billet and back up above - no obstructions, no overpulls. - Continue POH to window. 17:30 - 19:00 1.50 DRILL P PROD3 - RIH to 50' above billet - M/U TO & orient 90L. RIH wlo pump & tag billet @ 7581' wI 5K. P/U above billet, turn on pump, & in 30L setting. Orient 120L & RIH past billet wI no problem. 19:00 - 21 :30 2.50 DRILL P PROD3 - RIH to TD @ 12043' - hole slick. 21 :30 - 23:00 1.50 DRILL P PROD3 - Pump lo-vis weighted sweep & circ surface to surface @ 330 GPM 3700 psi, 90 RPM & reciprocating. - Calculated ECD 10.76, actual ECD 10.8 to 10.85. - Prepare for displacement by reducing surface volume. Pump 100 bbls MOBM into tank farm. Take on SFMOBM into pit 3. 23:00 - 00:00 1.00 DRILL P PROD3 - Displace MOBM wI SFMOBM @ 285 GPM 2650 psi, 90 RPM & reciprocating. 12/26/2004 00:00 - 01 :15 1.25 DRILL P PROD3 - Displace MOBM wI SFMOBM @ 285 GPM 2650 psi, 90 RPM, & reciprocating. 01:15 - 01:30 0.25 DRILL P PROD3 - BID TD - monitor well - static. 01 :30 - 05:30 4.00 DRILL P PROD3 - POH to 6000' - hole in excellent shape wI maximum 5K drag. No sign of billet while pulling by wI ADN stab or bit. 05:30 - 06:30 1.00 DRILL P PROD3 - Service TD. - Monitor well. 06:30 - 11 :30 5.00 DRILL P PROD3 - POH to 684'. 11 :30 - 19:00 7.50 DRILL N WAIT PROD3 - Stab TIW valve in string - monitor well wI hole fill pump on while waiting for weather to improve. Phase 3 conditions. - 6.5 bblloss for 7.5 hrs. 19:00 - 19:30 0.50 DRILL P PROD3 - PJSM for handling BHA & source - POH to BHA. 19:30 - 21:30 2.00 DRILL P PROD3 - UO BHA. 21 :30 - 22:00 0.50 CASE P PROD3 - Clear & clean floor. 22:00 - 22:30 0.50 CASE P PROD3 - Service TD & drawworks. 22:30 - 00:00 1.50 FISH P PROD3 - M/U Whipstock retrieving BHA as follows: Fixed lug retrieval hook, 1 jt 31/2" HWDP, bumper sub, oil jars, float sub, MWO, &XO. 12/27/2004 00:00 - 00:30 0.50 STWHIP P PROD3 - Continue M/U whipstock retrieving BHA. 00:30 - 02:00 1.50 STWHIP P PROD3 - RIH wI 8 stands HWDP. - Shallow test MWD & BID TD. 02:00 - 03:30 1.50 STWHIP P PROD3 - RIH wI whipstock retrieval ass'y on 4" DP to 4178'. 03:30 - 04:00 0.50 STWHIP P PROD3 - CBU to condition mud @ 285 GPM 1180 psi. - BID TO. 04:00 - 06:00 2.00 STWHIP P PROD3 - RIH wI 4" DP to -30' above whipstock. Fill pipe & orient hook wI MWD. - P/U wt 130K, SIO wt 105K. - RIH to 5' below top of whipstock @ 6402'. Engage slot in whipstock face - OK. P/U & release whipstock wI 65K over. - Monitor well. 06:00 - 07:00 1.00 STWHIP P PROD3 - CBU @ 250 GPM 1100 psi. 07:00 - 12:00 5.00 STWHIP P PROD3 - POH wI 4" DP to BHA. 12:00 - 14:00 2.00 STWHIP P PROD3 - UD BHA. - Clear floor of tools & clean tloor. 14:00 - 15:00 1.00 CASE P PROD3 - PJSM - R/U 4 1/2" liner running equip't. 15:00 - 19:00 4.00 CASE P PROD3 Run 4.5" slotted liner to 2484'. 19:00 - 20:00 1.00 CASE N RREP PROD3 Replace casing tongs. 20:00 - 22:30 2.50 CASE P PROD3 Continue running 4.5" slotted liner. 22:30 - 23:30 1.00 CASE N RREP PROD3 Replace cable on laydown machine. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11 /1 9/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 12127/2004 23:30 0 00:00 0.50 CASE P PROD3 Continue running 4.5" slotted liner to 4000'. 12/28/2004 00:00 - 03:30 3.50 CASE P PROD3 - RIH w/4 1/2" guide shoe jt, 116 jts 4 1/2" slotted liner & 16 jts 4 1/2" solid liner. - Avg M/U tq 3500 ftllbs. 03:30 - 04:00 0.50 CASE P PROD3 - CIO to 3 1/2" elevators. - P/U & M/U hook hanger. Total length of liner, hook hanger, & associated pup jts 5627.99'. - UD tubing tongs. 04:00 - 11 :30 7.50 CASE P PROD3 - RIH w/4 1/2" liner on 4" DP to 11921 '. - Worked through window on 2nd attempt after picking up above it & rotating string 1/2 turn. - Did not see aluminum billet @ 7581'. 11 :30 - 18:30 7.00 CASE P PROD3 o Attempt to hook hanger on window wlo success. Able to run hook 10' below window, but unable to get beyond 12017'. (TD @ 12043') 18:30 - 00:00 5.50 CASE N DFAL PROD3 - Monitor well. - POH to 7255' wI 4" DP slowly (3-4 min per stand) to prevent swabbing due to swell packers. - Strapping DP while POH. 12/29/2004 00:00 - 01 :00 1.00 CASE N DFAL PROD3 - POH wI 4" DP to hook hanger. - 1.84' difference in tally & SLM. 01 :00 0 03:30 2.50 CASE N DFAL PROD3 - CIO elevators & P/U hook hanger & inspect. No damage to hook or hanger. - R/U casing tongs & UD hook hanger & ball catcher assy. - UD 1 jt 4 1/2" slotted liner. - MIU hook hanger & ball catcher assy. - UD casing tongs. 03:30 0 11 :00 7.50 CASE N DFAL PROD3 - RIH wI hook hanger on 4" DP to 7013' - Tag up on liner tie back @ 6465" - P/U above TOW & rotate string 1/2 turn. Made it through window on 2nd attempt. - RIH to 11,900' 11 :00 - 14:00 3.00 CASE N DFAL PROD3 - String Wt. down 75-50k, up 170k - Attempted to set hook wlo success. Able to work hook 10' outside window, could not get below 11,976'. Decided to POOH and dress window. 14:00020:30 6.50 CASE N DFAL PROD3 - POH with 4" DP to hanger. 20:30 - 21 :30 1.00 CASE N DFAL PROD3 - Change elevators 3 1/2" - UD hanger - Change elevators to 4 1/2" 21 :30 - 00:00 2.50 CASE N DFAL PROD3 - PJSM - discussed risks associated with laying down liner - POH UD 16 jts 4 1/2" solid liner, 8 jts 4 1/2" slotted liner 1 x 1. - UD 2 swell packers. Original OD 6.4" - currently 6.53" 12/30/2004 00:00 - 07:30 7.50 CASE N DFAL PROD3 - POOH w/4 1/2" slotted liner. o Total jts. UD, 115 slotted, 16 solid, 1 shoe jt, 2 swell packers and 1 hook hanger. 07:30 - 08:30 1.00 CASE N DFAL PROD3 o Monitor well - RID TBG equipment - Clearlclean rig floor 08:30 - 09:00 0.50 BOPSUP P PROD3 - PJSM - Pulled wear bushing - Set test plug Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12130/2004 08:30 - 09:00 0.50 BOPSUF P PROD3 09:00 - 13:30 4.50 BOPSUF P PROD3 13:30 - 14:30 1.00 BOPSUF P PROD3 14:30 - 15:00 0.50 CASE N DFAL PROD3 15:00 - 17:30 2.50 CASE N DFAL PROD3 17:30 - 20:00 2.50 CASE N DFAL PROD3 20:00 - 23:00 3.00 CASE N DFAL PROD3 23:00 - 00:00 1.00 CASE N DFAL PROD3 12/31/2004 00:00 - 05:00 5.00 CASE N 05:00 - 07:00 2.00 CASE N 07:00 - 11 :00 4.00 CASE N 11 :00 - 12:00 1.00 CASE N 12:00 - 12:30 0.50 CASE N 12:30 - 13:30 1.00 CASE N 13:30 - 17:00 3.50 CASE N 17:00 - 21:00 4.00 CASE N - R/U test equipment - Test BOPE's - 3,500 psi. highl 250 psi. lowl 5 min. - Witness of test wavied by John Chrisp (AOGCC) - Pull test plug - Install wear bushing - Blow dn. test lines - RID test equipment - Cut apart bent shoe it. & slotted it. wI Wachs cutter - Clean out under rotary table (dried excess drilling fluid) - CIO air boot - PJSM - Build window polish mill assy. (2 ea. string mills @ 63/4" OD) - Test MWD before proceeding in hole - RIH wI 4" DP to 6300' (63 stds DP) - Fill DP every 2000' - Orient bent jt.1 MWD to 15 deg. left of HS and RIH to 6388' - P/U std # 64 & reorient and attempt to slide out window (TOW @ 6397' & BOW @ 6409'). Bottomed out in tie back sleeve @ 6461 '. No success after repeated attempts. DFAL PROD3 - Attempt to exit window wI polish mill assy. (circ. & non-circ.) - Positionlorient string @ 90 deg. increments & attempt exit - Rotate @ 6393' @ 10 rpm wlsteady 3500 ftllbs torque. Repeat @ 6405' (middle of window) with same results. - Rotate fl 6390' to 6420' @ 5 rpm wI 3000 ftllbs steady torque, (rotary limit set @ 3500 ftllbs.). Attempting to stall drill string @ window. No success - Positionlorient string @ 45 deg. increments & attempt exit - POH to 6358' (UD 1 jt.), orient to 9 deg. left of HS. RIH & P/U 1 it. and bottom out in tie-back sleeve @ 6461'. - Same as above but @ 14 deg. left of HS, no success. DFAL PROD3 DFAL PROD3 DFAL PROD3 DFAL PROD3 DFAL PROD3 DFAL PROD3 DFAL PROD3 - PJSM - Slip & cut drilling line. - POH w/4" DP - Pooh w/BHA, B/O & UD same - Clear & clean rig floor - PJSM - Strap and M/U BHA - RIH wI polish mill assy. #2 on 4" Dp to 6310' - String Wt. Up 130K, Dn 100K - Orient bent it. wI MWD - Pump Rate 80 spm @ 1340 psi. - During orienting process tagged btm of window @ 6409'. Unable to exit window after final orientation of bent jt.! MWD - Repeated attempts made wI different tool orientations WIO success - While roating Dn @ 5 rpm, wI 5,000 ft.llbs torque and running speed of 30 fpm tagged Btm of window @ 6409', string torqued up and stalled. Unable to pull free with up wt. of 130K. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 12131/2004 17:00 - 21 :00 4.00 CASE N DFAL PROD3 Released torque and applied 2 rds. to the left in 1/2 turn increments and worked torque Dn. Gradually increasing pick up wt. by 5,000 lb. increments. String pulled free @ 160K, proceeded to RIH and tag tie-back. - Repeated rotating Dn process same as before and tagged again. Continued to apply Rt. hand torque to 7,000 ft./lbs and increase bit wt. to 35K. String broke free and proceeded to RIH to 6465' to confirm string outside window. 21 :00 - 22:00 1.00 CASE N DFAL PROD3 - RIH to 6740' (bull nose depth), confirmed mills pass through window before prior start of dressing process. - Dress window w/20,25 & 30 rpm, 350 gpm pump w/1600 psi. - Work mills f/6390' t/6415' to dress window. - Work mills f/6415 t/6455' to dress open hole. - After dressing Up Wt. 125K, Dn Wt. 100K WIO rotating or circulating. - No abnormal Up Wt. or Dn. Wt. after dressing 22:00 - 22:30 0.50 CASE N DFAL PROD3 - POH t/6350' 22:30 - 23:30 1.00 CASE N DFAL PROD3 - Circ B/U @ 300 GPM 1350 psi. - Monitor well 23:30 - 00:00 0.50 CASE N DFAL PROD3 - POH wI mills 1/1/2005 00:00 - 03:30 3.50 CASE N DFAL PROD3 - POH wlpolish mill assy. to BHA 03:30 - 05:30 2.00 CASE N DFAL PROD3 -UD BHA 05:30 - 06:00 0.50 CASE N DFAL PROD3 - Clear floor of excess BHA tools - Clean floor 06:00 - 07:30 1.50 CASE N DFAL PROD3 - PJSM - R/U Tbg. handling equip. to RIH w/4 1/2" slotted liner 07:30 - 16:00 8.50 CASE N DFAL PROD3 - M/U & RIH with 41/2" liner. - Avg. make up torque 3600 ft.llbs. - 1 solid shoe jt., 116 jts. 4 1/2" slotted liner, 16 jts. 4 1/2" solid liner, 2 swell pkr. assy. 16:00 - 16:30 0.50 CASE N DFAL PROD3 - CIO elevators - M/U 7 5/8" x 41/2" Hook hgr. - String wt. Up 97K - String wt. Dn 87K 16:30 - 17:00 0.50 CASE N DFAL PROD3 - RID Tbg. handling equip. - R/U to RIH wI 4" DP 17:00 - 17:30 0.50 CASE N DFAL PROD3 - RIH wI slotted liner on 4" DP to 6461' (Tagged up on tie-back) 17:30 - 19:00 1.50 CASE N DFAL PROD3 - UD 2 jts. DP and P/U Std. # 10 of 4" DP (needed full std. to orient and exit window, allowing tag up on tie-back if needed) - Orient 1/4 turn to right and attempt exit window (no success) - Add another 3/4 turn (1 turn total) and exit window - P/U 2 jts. DP (same ones that were UD) and continue to RIH 19:00 - 23:30 4.50 CASE N DFAL PROD3 - RIH wI slotted liner on 4" DP - Tagged Billet in OBd lateral @ 7581' (rotate 1/2 turn to right and work by same, no problem) 23:30 - 00:00 0.50 CASE N DFAL PROD3 - Liner stopped @ 11215', Up Wt. 175K, Dn Wt. 75K - Reciprocate f/11, 180' t/11215' - Rotate 1 turn rt. & work torque dn. - Add 1 more turn rt. & work pipe - Add 3 more turns & work pipe until all torque gone. No success Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/19/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/1/2005 23:30 - 00:00 0.50 CASE N DFAL PROD3 1/212005 00:00 - 00:30 0.50 CASE N DFAL PROD3 - UD 1 it. (for longer stroke when reciprocating) - Rotate 1 turn rt. and reciprocate pipe and using drawworks braking action to work through tight spot @ 11215' 00:30 - 01 :30 1.00 CASE N DFAL PROD3 - RIH wI liner on 4" DP t/11,971'. - Up Wt. 167K - Dn Wt. 60K 01 :30 - 03:00 1.50 CASE N DFAL PROD3 - POH t/11 ,965' (hook hgr. @ 6392') - Apply 1 1/2 turns rt, unhook hanger and work pipe dn. to 11,980' - POH t/11 ,955' - Apply 3/4 turn rt. and work torque dn & attempt to hang hook hanger wlo success.. - Apply 1/2 turn and work torque dn. and hang off hgr. - P/U 10' and unseat hgr. and rehang same. (0215 hrs) - Drop 1 3/4" ball and chase w/30 spm @ 300 psi to seat same - Pressure up to 3,000 psi and release from liner - P/U and verify running tool released from liner - P/U Wt. 138K - SIO Wt. 112K - POH t/ 6360' 03:00 - 03:30 0.50 CASE P PROD3 - CBU @ 66 spm @ 1750 psi (2300 calc. stks) 03:30 - 04:30 1.00 CASE P PROD3 - RIH and tag top of Hook Hgr. @ 6392' - Blow Dn Top Drive - Monitor well 04:30 - 07:30 3.00 CASE P PROD3 - POH wI 4" DP 07:30 - 08:00 0.50 CASE P PROD3 - B/O & UD liner running tool 08:00 - 09:00 1.00 CASE P PROD3 - Clean & clear rig floor 09:00 - 09:30 0.50 CASE P PROD3 - PJSM - RIU to RIH wI LEM #1 & inner string 09:30 - 12:30 3.00 CASE P PROD3 - M/U LEM #1 Assy.; Seal Assy.-3 x 4 1/2" pup its.; Window Assy.- 41/2" pup it., Casing Swivel, Seal Bore Ex!. (inner string- 2 x 2 7/8" tbg. jts., 2 x 2 7/8" pup jts., Seals & Nozzle Assy.), ZXP Pkr. wI Tie-Back Assy. 12:30 - 19:00 6.50 CASE P PROD3 - RIH wI LEM #1 on 4" DP to 6390' (top of hook hgr. @ 6392'). - Running speed as per Baker Rep. was 30' prl min. - Up Wt. 135K - Dn Wt. 112K 19:00 - 20:00 1.00 CASE P PROD3 -Tagged Hook Hgr. top @ 6392' - Apply 1 1/2 turns to right & RIH t/6462' - Up Wt. 137K - Dn Wt. 110K - Continue t/ RIH & tag @ 6481' - Apply 1 1/2 turns & RIH, wlo success - Brk circ. @ 3 bpm @ 490 psi & circ. dn t/ 6490' (mule shoe depth). - LEM locator tagged up in Hook Hgr. Collet Profile @ 6392' - P/U 10' & SIO to verify LEM engaged wI 20,000# on Pkr. 20:00 - 22:00 2.00 CASE P PROD3 - Brk. TD connection & drop 1 3/4" pkr. setting ball - Circ. Ball Dn. @ 2 bpm @ 430psi. (bumped ball with 537 stks) Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11 /1 9/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/2/2005 20:00 - 22:00 2.00 CASE P PROD3 - P/U t/2800 psi. to set ZXP Pkr. (hold 5 min), bleed off pressure · Close upper pipe rams to test ZXP Pkr. x 7 5/8" csg. t/1500 psi., Unable to pressure up (pumped 9 bbls 1104 stks. to 700 psi.), bleed off excess pressure. Suspect Pkr. not fully set. · Open Rams - Pressure up DPI Pkr. t/ 4000 psi. to reset Pkr. (observed string wt. fluctuation of app. 10/15000 Ibs), hold 5 min. & bleed off pressure. Also released running tool during this process. - Close top rams & retest Pkr x 7 5/8" csg. wI 1500 psi., successful · Pick up 20' (out of pkr.) & rotate dn @ 25 rpm to verify Pkr. set. Tag LEM tie-back @ 6335', Pkr set @ 6346' - POH wI circ. sub t/6332' 22:00 . 23:00 1.00 CASE P PROD3 - Circ. B/U 6332' (reciprocating Dp) @ 6 bpm @ 1100 psi. (calc. stks 2400) · Blow Dn. TD 23:00 - 00:00 1.00 CASE P PROD3 - POH wI LEM running tool on 4" DP 1/3/2005 00:00 - 02:30 2.50 CASE P PROD3 · POH wI LEM running tool on 4" Dp 02:30 - 03:00 0.50 CASE P PROD3 · R/U 2 7/8" handling tools & equip. to UD inner string 03:00 - 03:30 0.50 CASE P PROD3 · B/O & UD LEM Running Tool 03:30 . 04:30 1.00 CASE P : PROD3 - UD 2 7/8" Inner string 04:30 - 05:00 0.50 CASE P , PROD3 - RID 2 7/8" handling tools & equip. 05:00 - 06:00 1.00 CASE P PROD3 - Clear & Clean rig floor 06:00 . 09:30 3.50 P WEXIT - PJSM - M/U Whipstock BHA fl OBa lateral (BHA length=1437.90') - Orient MWD t/ Whipstock - Shallow test MWD wI 200 gpm, Tool Pulse 360/460 psi. - BHA to Top of Slide---m1196.74' 51 stds 4" Dp + 25.47'---4908.10' Depth to Top of Slidem--61 07.87' 09:30 - 14:00 4.50 STWHIP P WEXIT - RIH wI Whipstock BHA on 4" Dp t/6323' - Run speed 90'1 min. · String Wt. Up 145K, Dn 11 OK 14:00 - 14:30 0.50 STWHIP P WEXIT - Engaged Pump, 300 gpm @ 1980 psi. · Reciprocate Dp & Orient Whipstock to 14 deg. Left (obtained 4 good tool faces) - RIH & set Whipstock Anchor, Top of Whipstock Slide @ 6108' - P/U to 15K overpull to verify Whipstock set - S/O and stacked 42K & Sheared Mills free 14:30·16:30 2.00 STWHIP P WEXIT - PJSM - Displace Well bore fluid t/ MOBM - 260 bbls @ 300 gpm @ 1980 psi - Circulated 2 X B/U to condition mud 16:30 - 21 :30 5.00 STWHIP P WEXIT - Mill Window f/6108' t/6120' (TD @ 6138') - WOM 2-3K, RPM 75-100 · Torque 8,000-9,000 ftIlbs - Pump 320 gpm @ 1800 psi - String Wt. Up 145K, Dn 107K Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/3/2005 16:30 - 21 :30 5.00 STWHIP P WEXIT - Retrieving Slot @ 6113' @ 14 deg. Left 21 :30 - 22:30 1.00 STWHIP P WEXIT - Circ. Sweep SIS (Sweep = 40 bbl MOBM + 55 gal. dm HRP) - Pump 320 gpm @ 1800 psi. - Ream & back ream window while sweep going around BHA - RIH through window dry before POH-no problem - Monitor Well -Static 22:30 - 23:00 0.50 STWHIP P WEXIT - POH t/ 5600' 23:00 - 00:00 1.00 STWHIP P WEXIT - PJSM - Slip and Cut Drlg Line 1/4/2005 00:00 - 02:00 2.00 STWHIP P WEXIT - PJSM - Slip & Cut 473' bad Drlg Line 02:00 - 04:00 2.00 STWHIP P WEXIT - POH wI Whipstock Mill Assy. 04:00 - 06:30 2.50 STWHIP P WEXIT - B/O & UD Baker Milling Tools - Stand back collars and HWDP 06:30 - 08:00 1.50 STWHIP P WEXIT - Clear rig floor of BHA components - Clear rig floor & under rotary table 08:00 - 08:30 0.50 STWHIP P WEXIT - Rig Service 08:30 - 12:30 4.00 STWHIP N RREP WEXIT - Repair Top Drive 12:30 - 13:30 1.00 STWHIP P WEXIT - M/U Stack Washer - Functioned BOPE stack & washed to remove metal cuttings - Flushed Choke, Kill & Flow lines - Blow Dn. TO, Kill & Choke lines 13:30 - 16:00 2.50 STWHIP P WEXIT - PJSM - P/U & M/U 63/4" Driectional Drlg. Assy. - Cleared rig floor, installed Radioactive sources - Continue to build BHA 16:00 - 19:30 3.50 STWHIP P WEXIT - RIH wI BHA on 4" Dp - Shallow pulse test MWD - Continue RIH t/ 6050' 19:30 - 20:30 1.00 STWHIP P WEXIT - Establish circulation & Drilg. parameters - String Wt. Rot. 11 OK - Up Wt. 120K, Dn Wt. 105K - ECD 10.0 ppg (calculated) - Pump 330 gpm @ 2300 psi - Set Tool Face 14 deg. left - Slide through window (6108'-6120') wlo pump t/ 6130' - Circ Dn. fl 6130' t/6138' 20:30 - 00:00 3.50 DRILL P PROD4 - Drlg. f/6138' t/6340' (rotating & sliding) - WOB Sliding 3/4K - Wob Rot. 5K - Rpm 60 - Torque- Off btm 7,000 ftllbs, On Btm 8,000 ftllbs - Pump Rate 330 gpm - Pressure-Off Btm 2300 psi, On Btm 2400 psi - Calc. ECD 10.0, Act ECD. 10.2 1/5/2005 00:00 - 02:30 2.50 DRILL P PROD4 - Drlg. fl 6340' t/ 6528' (rotating & sliding) - WOB Sliding 3/4K - WOB Rot. 5K - Rpm 60 - Torque- Off btm 7,000 ftllbs, On Btm 8,000 ftllbs - Pump Rate 330 gpm - Pressure-Off Btm 2300 psi, On Btm 2400 psi - Calc. ECD 10.0, Act ECD. 10.2 Printed: 2n/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/5/2005 02:30 - 03:00 0.50 DRILL P PROD4 - Circulate, as per Geolgist (waiting on MWD logs) - Pump Hi-Vis Sweep (40 bbl MOGM + 55 gal HRP) - Pump Rate 330 gpm @ 2250 psi. - Reciprocating, oriented high-side PROD4 - Drlg. fl 6528' t/7292' (rotating & sliding) - WOB Sliding 3/4K - WOB Rot. 7/8K - Rpm 80 - Torque- Off btm 5,000 ftllbs, On Btm 6,000 ftllbs - Pump Rate 330 gpm - Pressure-Off Btm 2400 psi, On Btm 2600 psi - Calc. ECD 10.18, Act ECD. 10.4 - Strg. WI. Up 122K, DN 93K, Rot. Wt 108K 03:00 - 12:00 9.00 DRILL P 12:00 - 00:00 12.00 DRILL P PROD4 - Drlg. f/7292' t/ 8444' (rotating & sliding) - WOB Sliding 2K - WOB Rot. 3/4K - Rpm 80 - Torque- Off btm 7,000 ftllbs, On Btm 9,000 ftllbs - Pump Rate 330 gpm - Pressure-Off Btm 2610 psi, On Btm 2760 psi - Calc. ECD 10.4, Act ECD. 10.5 - Strg. Wt. Up 125K, DN 88K, Rot. Wt 109K PROD4 - Drlg. f/8444' t/9310' (rotating & sliding) - WOB Sliding 4K - WOB Rot. 5K - RPM 80 - Torq. On Btm. 7K, Off Btm. 6K - Pump Rate 330 gpml 92 spm - Pump Press. Off Btm. 3100 psi, On Btm 3300psi - Strg. Wt. Up 127K, Dn 98K, Rot. 105K - Calc. ECD. 10.47, Act ECD. 10.39 - SPR #1 30 spm=590 psi 40 spm=780 psi - SPR #2 30 spm=700 psi 40 spm=880 psi - ART =6.71 hrs. AST =1.29 hrs. 1/6/2005 00:00 - 12:00 12.00 DRILL P 12:00 - 00:00 12.00 DRILL P PROD4 - Drlg. f/9310' t/10,433' (rotating & sliding) - WOB Sliding 5/22K - WOB Rot. 4K - RPM 80 - Torq. On Btm. 8K, Off Btm. 6K - Pump Rate 330 gpml 92 spm - Pump Press. Off Btm. 3,000 psi., On Btm. 3100 psi. - Strg. Wt. Up 139K, Dn. 94K, Rot. 113K Printed: 217/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/6/2005 12:00 - 00:00 12.00 DRILL P PROD4 - Calc. ECD 10.25, Act ECD 10.27 - ART =3.51 hrs., AST =2.82 hrs. 1/7/2005 00:00 - 10:30 10.50 DRILL P PROD4 -Drlg. f/1 0,433' t/11,006' (rotating & sliding) - WOB; Sliding 22/25K, Rot 5K - RPM 80 - Torq. Off Btm. 6K, On Btm 8K - Pump Rate 330 gpml 92 stks - SSP; On Btm 3150 psi., Off Btm 3000 psi - Strg. Wt., Up 139K, Dn. 94K, Rot 113K - ECD; Calc. 10.39, Act 10.43 - SPR #1 30 spm=680 psi. 40 spm=850 psi. - SPR #2 30 spm=680 psi. 40 spm=880 psi. - Observed intermittent high torque causing rotary to stall ( torque limiter set at 12,000 ftIlbs). Decision was made to back ream through inverted section of low permeability zone fl 10,150' t/1 0,900' 10:30 - 14:30 4.00 DRILL P PROD4 - Backream f/11 ,006' t/ 9,950' Through inverted low permeability section. - RPM 80, Torque 7-9K - Pump rate; 330 gpm @ 2950 psi. - String stalled out @ 15,000 ft/lbs torque @ following depths; - 10,900'-10850',10,725'-10,700',10,600'-10,575', 10,488'-10,450' 10,358'-10,298',10,164'-10,138',10.094'-10,044' - RIH t/11 ,006' 14:30 - 16:00 1.50 DRILL P PROD4 - Reciprocate & rotate @ 11,006' while circulating - Pump & circ. 40 bbl. weighted sweep SIS - Pump rate 330 gpm @ 2850 psi. - RPM 80 16:00 - 18:30 2.50 DRILL P PROD4 - Drlg f/11,006' t/11, 197' (rotating & sliding) - WOB; Sliding 25K, Rot. 4K - RPM 80 - Torque; On Btm. 8/1 OK, Off Btm. 7K - Pump; 330 gpml 92 stks. - SSP; On Btm 3130 psi., Off Btm 2980 psi. - Strg Wt.; Up 140K, Dn.87K, Rot. 115K - ECD; Calc. 10.53, Act. 10.54 - Rotary on TD failed (unable to rotate at all). Continue to circ. and reciprocate pipe while preparing to trouble shoot rotary fail ure 18:30 - 21 :00 2.50 DRILL N RREP PROD4 - Trouble shoot TD rotary failure (reciprocating and circulating during this process). - Pump; 330 gpm @ 2960 psi. - Strg Wt.; Up 143K, Dn.90K - Suspect rotary rheostat-replace same 21 :00 - 00:00 3.00 DRILL P PROD4 - Drlg f/11 ,006' t/11 ,390' (rotating & sliding) Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/7/2005 21 :00 - 00:00 3.00 DRILL P PROD4 - WOB; Sliding 25K, Rot. 3K - RPM 80 - Torque; On Btm. 7K, Off Btm. 6K - Pump; 330 gpml 92 stks. - SSP; On Btm 3200 psi., Off Btm. 3000psi. - Strg Wt.; Up 142K, Dn. 80K, Rot. 115K - ECD; Calc. 10.76 Act. 10.79 1/8/2005 00:00 - 07:00 7.00 DRILL P PROD4 - Drlg. f/11 ,390' t/12,1 00' (rotating & sliding) - WOB; Sliding 4K Rot. 5K - RPM 80 - Torque; On Btm. 7,500 Wlbs, Off Btm. 7,000 Wlbs. - Pump Rate 330 gpml 92 spm - SSP; On Btm. 3,280 psi. Off Btm. 3,150 psi. - Strg. Wt.; Up 150K, Dn.75K, Rot. 114K - ECD; Calc. 10.68 Act. 10.85 - SPR #1 30 spm=720 psi. 40 spm=900 psi. - SPR #2 30 spm=800 psi. 40 spm=900 psi. 07:00 - 09:00 2.00 DRILL P PROD4 - Circ. Btms. Up x 2, until shaker returns were clean. - Pump Rate; 330 gpm @ 3,200 psi. 09:00 - 14:00 5.00 DRILL P PROD4 - Wiper Trip f/12, 1 00' t/ 6,040' - Tight Spot @ 10,596', 20K overpull, wrk'd BHA through area, no overpull after working area. 14:00 - 16:30 2.50 DRILL P PROD4 - Circ. Btms. Up x 2 @ 6,040' - Pump Rate 330 gpm @ 2,250 psi. 16:30 - 00:00 7.50 DRILL N WAIT PROD4 - Circulate @ 6,040', Phase 3, Wait On Weather - Pump Rate 90 gpm @ 340 psi. - Strg. Wt.; Up 115K, Dn. 105K, Rot. 111 K - Reciprocating & Rotating Drill string periodically 1/9/2005 00:00 - 00:00 24.00 DRILL N WAIT PROD4 - Circulate @ 6,040', Phase 3, Wait On Weather - Pump Rate; 90 gpm @ 340 psi. - Strg. Wt.; Up 115K, Dn. 105K, Rot. 111 K - Reciprocating & Rotating periodically 1/10/2005 00:00 - 00:00 24.00 DRILL N WAIT PROD4 - Circ. @ 6,040', Phase 3, Wait On Weather - Pump Rate; 90 pgm @ 340 psi. -Strg.Wt.;Up115K, Dn.105, Rot.11K - Reciprocating & Rotating Dp périodically 1/11/2005 00:00 - 06:00 6.00 DRILL N WAIT PROD4 - Circ @ 6,040', Phase 3, Wait On Weather - Pump Rate; 90 gpm @ 340 psi - Strg. Wt.; Up 115K, Dn.105K, Rot. 11K - Reciprocate & Rotate periodically 06:00 - 18:00 12.00 DRILL N WAIT PROD4 - Phase 3 lifted to Phase 2 - Continue to Circ. @ 6,040' - Mobilize equipment to clean pad & dig out all vac. trucks. 2 forklifts, 1 cat & service vehicles to start dead trucks - Send Vac. trucks wI SFMOBM back to M-I plant for reheating wI additions of new mud. 18:00 - 00:00 6.00 DRILL N WAIT PROD4 - Circ. @ 6,040',90 gpm 1340 psi. - Clear and clean around rig & pad wI heavy equipment Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/11/2005 18:00 - 00:00 6.00 DRILL N WAIT PROD4 - Clear all exits, walkways, stairs & steps of excess snow & ice 1/12/2005 00:00 - 00:30 0.50 DRILL P PROD4 - B/O TD & Blow Dn same. Change out first jt. (galled face on tool jt) 00:30 - 02:30 2.00 DRILL P PROD4 - RIH wI 4" Dp & 63/4" Directional BHA t/9,293' - Dn. Wt. 75K 02:30 - 03:30 1.00 DRILL P PROD4 - M/U TD, Fill Dp & Brk. Circ. (stage up pumps in 30 stk. increments) - Final Pump Rate; 325 gpm @ 2,760 psi. - ECD Calc. 10.35, Act. 10.56 - B/O TD & Blow Dn. same 03:30 - 04:30 1.00 DRILL P PROD4 - RIH wI 4" Dp & 63/4" BHA t/12, 100' 04:30 - 08:00 3.50 DRILL P PROD4 - M/U TD & Brk Circ. - Pump Rate; ICP 330 gpm 13,550 psi., FCP 330 gpm I 3,400 psi - RPM 100 - Torque 8,000 ftllbs - Strg. Wt. Up 112K, Dn. 102K, Rot 108K - ECD Calc. 10.80, Final Act. 10.89 - Pump 20 bbl. Low-Vis sweep followed by 20 bbl. Weighted sweep 08:00 - 10:30 2.50 DRILL P PROD4 - PJSM - Disp. Wellbore to SFMOBM @ 6 bpm I 2,370 psi. 10:30 - 13:00 2.50 DRILL P PROD4 - Circ. t/ condition & balance mud in wellbore - Pump Rate; 330 gpm 13,750 psi. 13:00 - 22:00 9.00 DRILL P PROD4 - PJSM - POH wI 4" Dp, UD jts. wI bad hard band (Dp & HWDP) - No significant overpull at window (6,120'-6,108') - 84 jts 4" Dp & 8 jts. HWDP UD 22:00 - 00:00 2.00 DRILL P PROD4 - POH wI 6 3/4" Directional BHA - PJSM wI Schlumberger before POH wI Radioactive Source - Clear floor of unnecessary personnel & remove source 1/13/2005 00:00 - 01 :00 1.00 DRILL P PROD4 - UD 6 3/4" Directional BHA 01 :00 - 02:00 1.00 CASE P PROD4 - Clear & Clean Rig Floor 02:00 - 02:30 0.50 CASE P PROD4 - Service Top Drive 02:30 - 05:00 2.50 CASE P PROD4 - P/U & M/U Whipstock Retrieving BHA - Retrieval Hook, 1 jt. HWDP, Float Sub, MWD, Bumper Sub, Oil Jar, XO, 24 jts. HWDP= 832.55' - Shallow Test MWD @ 830' - Pump Rate; 330 gpm 11000 psi. OK 05:00 - 08:00 3.00 CASE P PROD4 - RIH wI 4" Dp & Whipstock Retrieval BHA t/5,700' - SLM Dp in derrick while RIH - Fill Dp @ 3,200' Printed: 2/7/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: Rig Release: Rig Number: 11/19/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/13/2005 08:00 - 09:30 1.50 CASE P PROD4 - PJSM - Slip & Cut Drlg. Line 09:30 - 11 :00 1.50 CASE P PROD4 - RIH t/6,090' wI Whpstck Ret'r BHA on 4" Dp - Pump Rate; 250 gpm/1230 psi. - Strg. Wt; Up 130K, Dn. 102K - Orient'd Ret'r Hook, RIH t/6113' & latched Whpstck. - Pulled 30,000# Overpull & let Jars bleed off - Pull to 85,000# Overpull & released Anchor - POH 45' to 6,075' 11 :00 - 11 :30 0.50 CASE P PROD4 - CBU @ 330 gpm/1 ,950 psi - Pump Off- Monitor Well- Static - B/O & BID Top Drive 11 :30 - 14:30 3.00 CASE P PROD4 - POH wI 4" DP 14:30 - 17:00 2.50 CASE P PROD4 - BIO & UD Whpstck Retrieving BHA & Whipstock - Whipstock showed mills came off @ 9 1/2' , rode high side fl 1 1/2' 17:00 - 17:30 0.50 CASE P PROD4 - Clear & Clean Rig Floor 17:30 - 23:00 5.50 CASE P PROD4 - PJSM - Remove Wear Ring, Install Test Plug & R/U t/ test - Test BOPE's t/250 psi low/3,500 psi high - Test witnessed by AOGCC rep. - RID Test Equip., Remove Test Plug & Install Wear Ring 23:00 - 00:00 1.00 P RUNPRD - PJSM - R/U Liner running equip. & handling tools 1/14/2005 00:00 - 06:30 6.50 CASE P RUNPRD - Liner Running Procedure reviewed in PTSM - RIH wI 141 jts. 4 1/2" 12.6 # L-80 IBT Slotted Liner, 1 jt. 4 1/2" 12.6 # L-80 IBT Solid Liner (Bent) Shoe Jt. wI Guide Shoe, 1 jt. 4 1/2" 12.6# L-80 IBT Solid Liner under Hgr. - Torque to preset make, Avg. M/U Torque 3,450 ftIlbs. 06:30 - 07:30 1.00 CASE P RUNPRD - CIO Elevators - M/U Hook Hgr, P/U 1 std. Dp & M/U Top Drive - Circ. 10 bbls through Hgr. @ 330 gpm I 275 psi. - B/O TD & Blow Dn. Same - Strg Wt. Up 100K, Dn. 90K 07:30 - 17:30 10.00 CASE P RUNPRD - RIH w/4 1/2" Liner on 4" Dp - Worked Centrilizers through window, Centrilizers hung up @ 7,800', 8,470', 8,780' - Encountered difficulty RIH wI Liner, (corresponding Shoe Depth 10,300'). Beginning of Inverted section on Low Permability Zone of OBa @ 10,290'. - @ 11,604' began PIU single jts. Dp (1 x 1) & RIH, (giving more flexability to work string). Continue to work pipe Dn. t/ 12,082' - Did not latch HGR. Hook going through window @ 6,120' - Strg Wt. Up 190K, Dn. 40K 17:30 - 18:30 1.00 CASE P RUNPRD - Reciprocate pipe f/12,065' t/12,082', (free up liner string prior to attempting to hook Hgr). - Final Strg. Wt. Up 180K, Dn.40K - M/U TD & apply 1/4 turn to right. Work pipe & SIO to latch Hgr. Hook @ 6,120'-successful - P/U t/190K & brk. string free, unlatch Hgr. Hook - S/O & relatch Hgr. Hook @ same mark, depth 6,120'. - B/O TD & drop 1 3/4" Baker ball. M/U TD Printed: 2/7/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1114/2005 17:30 - 18:30 1.00 CASE P RUNPRD - Circ Ball Dn. @ 4 bpm/530 psi., reduce rate t/2 bpm last 10 bbls. Total string vol. to ball seat = 55 bbls. - Seat ball & pressure up t/3,000 psi. (hold 5 min.) - Bleed off pressure t/ 0 psi. - PIU 30' to app. 6,090' to verify Running Tool released. Continue to POH t/ 6,030' 18:30 - 19:30 1.00 CASE P RUNPRD - CBU @ 6,030' - Pump Rate; 355 gpm I 3,300 psi. - Strg. Wt. Up 125K, Dn. 108K - B/O TD & BID same 19:30 - 22:00 2.50 CASE P RUNPRD - POH wI 4" Dp & Liner Running Tool 22:00 - 22:30 0.50 CASE P RUNPRD - UD 4 1/2" Liner Running Tool - Make all service brks. as per Baker Rep. 22:30 - 23:00 0.50 CASE P RUNPRD - Clear & Clean Rig Floor 23:00 - 23:30 0.50 TIEBAC P OTHCMP - PJSM - R/U Liner Running Equip. & Handling Tools fl LEM # 2 23:30 - 00:00 0.50 CONDHL P OTHCMP - RIH wI LEM Assy. # 2 - 41/2" Seal Assy. 1 jt. 41/2" 12.6 # L-80 IBT Solid Liner 1/15/2005 00:00 - 01 :00 1.00 TIEBAC P OTHCMP - RIH wI LEM Assy. #2 - P/U 3 ea. 4 1/2" 12.6# L-80 IBT Solid Liner jts., 3 ea. 4 1/2" 12.6# L-80 IBT Solid Liner Pup jts., 1 ea. Baker LEM Hgr., 1 ea. Baker Seal Bore Assy. 01 :00 - 01 :30 0.50 TIEBAC P OTHCMP - PJSM - CIO Elevators - Install False Bowl & R/U 2 7/8" handling tools 01 :30 - 02:00 0.50 TIEBAC P OTHCMP - Service Top Drive 02:00 - 05:00 3.00 TIEBAC P OTHCMP - P/U & RIH wI Circ. Nozzle Assy., 9 jts. 2 7/8" 7.7# Inner Wash String & 2 7/8" Pack-Off Assy. - Total Length = 281.11' - CIO Elevators - P/U & M/U Baker 5 1/2" x 7 5/8" ZXP L TP 05:00 - 05:30 0.50 TIEBAC P OTHCMP - RID 2 7/8" Handling Tools 05:30 - 12:30 7.00 TIEBAC P OTHCMP - PJSM - RI H wI LEM #2 on 4" DP t/ 6,103' (top of Liner Hook Hgr) 12:30 - 15:00 2.50 TIEBAC P OTHCMP - M/U TD & Brk Circ. @ 3 bpml 570 psi. - Strg. Wt. Up 132K, Dn 111 K - Attempted to run LEM Assy. through Hgr. LEM window, wlo success, stacked out @ 6,122'. - P/U 20', turned string in increments of 1; 1/2; 1/4; 1/8 turns attempting to RIH, wlo success, string stacked out @ 6,122'. Continued to attempt to run through LEM window with & without pumps wlo success. Rotate string @ 5 rpm (strg. torque 4K ftllbs) while slacking off through window area wlo success, stacked out @ 6,122' - BID Top Drive 15:00 - 17:30 2.50 TIEBAC N DPRB OTHCMP - POH wI 4" DP & LEM #2 17:30 - 18:00 0.50 TIEBAC N DPRB OTHCMP - PJSM - R/U False Bowl & 2 7/8" Handling Tools 18:00 - 20:00 2.00 TIEBAC N DPRB OTHCMP - UD ZXP L TP & 2 7/8" Pack-off Assy. - CIO Elevators - POH 2 7/8" Inner string (stand back in derrick) - UD 2 7/8" Circ. Nozzle Shoe Assy. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 16:00 - 17:00 1.00 TIEBAC N DPRB OTHCMP - No abnormal wear or marks on 2 7/8" Circ. Nozzle Shoe DPRB OTHCMP - C/O Elevators - RID 2 7/8" Equip. & Handling Tools - R/U 4 1/2" Equip. & Handling Tools DPRB OTHCMP - POH wI Seal Bore Assy., LEM Hook Hgr., Solid Liner, Seal Assy. - 41/2" Mule Shoe lightly scarred in 6 different places around outside perimeter of shoe. Suspect contact wI Collet Profile of Liner Hook Hgr. - RIH w/4 1/2" Bent Seal Assy. JI. (bend 9' from shoe wI 6" off-set), 4 ea. 4 1/2" solid liner jts., 3 ea. 4 1/2" solid liner pup jts., LEM Hook Hgr, Seal Bore Assy. - CIO Elevators - RID 4 1/2" Equip. & Handling Tools - R/U 2 7/8" Equip. & Handling Tools - RIH w/2 7/8" Circ. Nozzle Assy. jl., 8 ea. 27/8" Tbg. jts., 5 ea. 27/8" Tbg. Pup jts., Pack-Off Assy. (total length = 279.21 ') - 2 7/8" Circ. Nozzle located 1.97' outside btm. of 4 1/2" Seal Assy. Mule Shoe DPRB OTHCMP - C/O Elevators - PIU & M/U ZXP L TP to 2 7/8" Inner String & 4 1/2" Outer String - M/U TD & Brk. Circ. @ 4 bpml 350 psi. - LEM Assy. Strg WI. Up 45K, Dn. 50K DPRB OTHCMP - Service Top Drive DPRB OTHCMP - RIH wI LEM #2 on 4" Dp t/6,055' - Strg. WI. Up 133K, Dn. 11 OK DPRB OTHCMP - RIH t/6,1 03', Tag'd Up on Top of Hook Hgr. Rotated string 1 turn & attempted to RIH wI LEM Assy. Through Liner Hook Hgr. LEM Window, Stacked Out @ 6,122'. M/U TD & brk. circ., 3 bpml 500 psi. Turned string in increments of 1; 1/2; 1/4; 1/8; turns attempting to exit LEM window wlo success. Continued to stack out @ 6,122'. Continued to attempt to exit LEM window. Occasionally the Mule Shoe Stacked Out @ 6,117', this depth corresponds with end of Hook Hgr. LEM Window. Continued to attempt to exit window using alternating braking actions & different running speeds wlo success. Rotated string at 5, 10, 20 rpm, Torque 4,500 ftIlbs while slacking off wlo success. DPRB OTHCMP - BID TD - POH wI LEM #2 on 4" Dp - SLM on trip out-no change in DP measurment DPRB OTHCMP - PJSM - B/O & UD ZXP L TP - POH w/2 7/8" Inner Wash String & stand back in derrick - Inspect & UD Circ. Nozzle Shoe Assy. - NO new addtional scarring or marks on Nozzle Shoe DPRB OTHCMP - POH & UD Seal Bore Assy., LEM, 3 ea. 4 1/2" Solid Liner pup jts. 3ea. 4 1/2" Solid Liner jts. - POH w/1 jl. liner & Bent JI. Seal Assy. - 4 1/2" Mule Shoe had severe scarring from btm. of shoe up through first set of seals. Remove damaged mule shoe and seals fl bent jl. & replaced them with shoe and seals from the 1/15/2005 18:00 - 20:00 20:00 - 20:30 2.00 TIEBAC N 0.50 TIEBAC N 20:30 - 21 :30 1.00 TIEBAC N 21 :30 - 22:30 1.00 TIEBAC N DPRB OTHCMP 22:30 - 23:00 0.50 TIEBAC N DPRB OTHCMP 23:00 - 00:00 1.00 TIEBAC N DPRB OTHCMP 1/16/2005 00:00 - 00:30 0.50 TIEBAC N 00:30 - 01 :00 01 :00 - 06:30 0.50 TIEBAC N 5.50 TIEBAC N 06:30 - 12:00 5.50 TIEBAC N 12:00 - 15:00 3.00 TIEBAC N 15:00 - 16:00 1.00 TIEBAC N Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/16/2005 16:00 - 17:00 1.00 TIEBAC N DPRB OTHCMP 17:00 - 17:30 0.50 TIEBAC N DPRB OTHCMP 17:30 - 18:30 1.00 TIEBAC N DPRB OTHCMP 18:30 - 20:00 1.50 TIEBAC N DPRB OTHCMP 1/17/2005 20:00 - 00:00 00:00 - 00:30 4.00 TIEBAC N 0.50 TIEBAC N 00:30 - 03:00 2.50 TIEBAC N 03:00 - 04:00 1.00 TIEBAC N 04:00 - 08:00 4.00 TIEBAC N 08:00 - 10:00 2.00 TIEBAC N 10:00 - 11 :30 1.50 TIEBAC N 11 :30 - 16:30 5.00 TIEBAC N 16:30 - 17:30 1.00 TIEBAC N 17:30 - 21 :30 4.00 TIEBAC N 21 :30 - 00:00 2.50 TIEBAC N orginal seal assy. jt which was not damaged during the first attempt to land LEM #2. - Clear & Clean Rig Floor - Remove Master bushings and vacum out old MOBM from drip pan area. - RIH w/4 1/2" Bent Jt. wI reconditioned mule shoe and seals installed. 4ea.4 1/2" Solid jts., 3 ea. 4 1/2" Pup jts., LEM & new Seal Bore Assy wlo swivel - RIH w/2 7/8" Tbg. Inner string (total length = 275.16') - 2 7/8" Nozzle Shoe protruding .84' beyond btm. of 41/2" Mule Shoe - P/U ZXP L TP & M/U to 2 7/8" inner string & to 5 1/2" Seal Bore Assy. DPRB OTHCMP - RIH wI LEM #2 on 4" Dp t/ 5,225' DPRB OTHCMP - RIH wI LEM #2 on 4" Dp t/6,056' - Strg Wt. Up 132K, Dn. 11 OK DPRB OTHCMP - RIH t/6,097', Tag'd Top of Liner Hgr. Rotated 1/4 turn & continued in hole to 6,117'. P/U above Liner Hgr. Top @ 6,097' & apply 1/4 turn in string and attempt to exit Liner Hook Hgr. LEM Window wlo success. Continue to work pipe and apply 1/4 turn increments for each P/U & S/O cycle for 2 full revolutions attempting to exit window wlo success. Still stacking out @ 6,117'. String hanging up @ 6,112 and then breaking loose when 5K Dn. Wt. applied. Suspect mule shoe oriented towards window, (btm. of Liner Hook Hgr. LEM exit window @ 6,111 '), but still unable to exit. Apply alternating braking action while slacking off trying to bounce mule shoe out window wlo success. Circ. @ 3 bpml 500 psi wI no effect. DPRB OTHCMP DPRB OTHCMP DPRB OTHCMP DPRB OTHCMP DPRB OTHCMP DPRB OTHCMP DPRB OTHCMP DPRB OTHCMP - CBU @ 5 bpml 920 psi - Monitor Well, Static - Blow Dn Top Drive - POH wI LEM #2 assembly on 4" DP. - Change elevators and rack back 3 stds 2 7/8" inner string. - LD 4 1/2" tubing fl LEM #2. Inspect seal assembly - no obvious signs of scoring or other damage. All seals intact. - Discuss options wI Anchorage and agree way forward. Wait on additional tools to be delivered to site from Baker. Cleaning & general housekeeping while waiting. - RIH w/2 7/8" Tbg fl derrick and POH & UD same - P/U Baker "HR" Liner Running Tool Assy. & RIH on 4" Dp t/ 6,075' - Establish Working Parameters - Strg. Wt; Up 132K, Dn 120K, Rot. 130K - Rotary; 10 RPM @ 4,500 Wlbs Torque - RIH t/6,097', Tagged Top of Liner Hook Hgr. Continued to RI H & btm'd out in "HR" profile of the Liner Hook Hgr. @ 6,116' - PIU 10' to verify Running tool engaged. SIO & stack 20,000# Dn. to verify Running Tool was seated in profile area. - S/O trying to break string free down, no success Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/17/2005 21 :30 - 00:00 2.50 TIEBAC N DPRB OTHCMP - P/U in 25,000# increments working pipe in attempt to free liner. @ 300,000# liner came free. Work pipe fl 6,107' t/ 6,129' ("HR" Running Tool Depth) until constant hook loads were established @ Up Wt. 185K & Dn. Wt. 70K. - @ 6105' apply 1 1/2 turn, S/O and attemp to hang Liner Hook Hgr. wlo success. Repeated attempts were made w/1, 3/4, 1/2, 1/4 turns being applied at different intervals while working string fl 6,107' t/ 6,129', wlo success. These depth settings were established to keep the top of the Liner Hook Hgr. inside the window @ 6,108' while the "HR" Profile of the Liner Hook Hgr. was outside the window app. 9/10' @ 6,129'. - Install 6 turns in string and trap torque of 4,500 ftllbs. Work pipe through window area. No change in trapped torque. - Suspect dogs on "HR" Running Tool not engaging properly in order to turn Hook Hgr. - P/U t/5,990' & rotate string @ 10 rpm wI 6,500 ft.lbs. torque. Torque being steady @ 6,500 ftllbs verifies that tool is turning, not the liner Hook Hgr. & 4 1/2" Slotted Liner 1/18/2005 00:00 - 02:00 2.00 TIEBAC N DPRB OTHCMP - Work Drlg. String fl 6,107' t/ 6,129' attempting to hang Liner Hook Hgr. @ btm. of widow @ 6'120'. Rotating Dp. in 1/4 turn increments to change location of hook assy. in attempts to find window., wlo success. - Continue to work string while communicating wI Anc. personal on plan forward. - Decision was made to POH wI Hook Hgr. Assy. & 4 1/2 "Slotted Liner 02:00 - 06:00 4.00 TIEBAC N DPRB OTHCMP - POH wI Liner Hook Hgr. & 4 1/2" Slotted Liner 06:00 - 07:00 1.00 TIESAC N DPRB OTHCMP Lay down hook hanger assembly. 07:00 - 08:30 1.50 TIESAC N DPRB OTHCMP Clean rig floor. Service rig and TDS. 08:30 - 11 :00 2.50 TIEBAC N DPRB OTHCMP Discuss plan forward with Anchorage team. Rig up to lay down 4.5" liner. 11 :00 - 19:00 8.00 TIEBAC N DPRB OTHCMP Pull and lay down 4.5" liner. Salvage usable centralizers. 25 centralizers damaged beyond future use. 19:00 - 20:00 1.00 TIEBAC N DPRB OTHCMP Rig down 4.5" liner equipment. Clear and clean rig floor. 20:00 - 21 :00 1.00 TIEBAC N DPRB OTHCMP Pick up mill assembly. 21 :00 - 23:00 2.00 TIESAC N DPRB OTHCMP RIH with milling assembly. Tag no-go at 6,348'. 23:00 - 00:00 1.00 TIESAC N DPRB OTHCMP Pull up to 6,113' and attempt to orient to window. Up Wt=125K Dn Wt=102K 1/19/2005 00:00 - 03:30 3.50 TIESAC N DPRB OTHCMP Continue attempting to pass through window. Tried slow rotating while lowering pipe, cease rotation and advancing orientation by 1/4 turns and advancing orientation by 1/8 tums. No success. 03:30 - 06:00 2.50 TIEBAC N DPRB OTHCMP POH with mill assembly to change BHA configuration. 06:00 - 07:00 1.00 TIEBAC N DPRB OTHCMP Break out & LD BHA #24 components. 07:00 - 07:30 0.50 TIEBAC N DPRB OTHCMP Service top drive. 07:30 - 10:00 2.50 TIEBAC N DPRB OTHCMP PU components for SHA #25. Bullnose, 4" pup jt, 4" bent jt, 2 its 4" DP, MWD, 9 jts 4",2 ea string mills 6.75" OD, 1 it 4" HWDP, jars, also 5 associated crossovers. Orient bent it with MWD. 10:00 - 11 :00 1.00 TIEBAC N DPRB OTHCMP RIH & shallow test MWD. 11 :00 - 13:30 2.50 TIEBAC N DPRB OTHCMP RIH to window depth at 6108'. 13:30 - 14:30 1.00 TIEBAC N DPRS OTHCMP Orient 15L with MWD. RIH & tag up on L 1 liner top. POH above Printed: 217/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/19/2005 13:30 - 14:30 1.00 TIEBAC N DPRB OTHCMP window and make 2 attempts RIH & POH with slow pipe rotation, trying to find window with a torque increase - no success. Orient bent joint @ 13R and go thru window into open hole. 14:30 - 15:30 1.00 TIEBAC N DPRB 10THCMP Work mills up & down thru window from 6102' to 6140' x5. Didn't see any indications that mills were doing any work downhole from torque or rotary indications. Make one pass without rotating and one pass without rotary or pump - no problems. 15:30 - 16:30 1.00 TIEBAC N DPRB OTHCMP Pull into shoe and circulate bottoms up. Inspect derrick for ice or other hazards. 16:30 - 19:00 2.50 TIEBAC N DPRB OTHCMP Monitor well. Blow down TDS. POOH to BHA. 19:00 - 21:00 2.00 TIEBAC N DPRB OTHCMP Lay down Milling assemby and MWD (BHA # 25). 21 :00 - 21 :30 0.50 TIEBAC N DPRB OTHCMP Clear and clean rig floor. 21 :30 - 00:00 2.50 TIEBAC N DPRB OTHCMP PJSM. Rig up and run 4.5" liner as per running detail to 1246' 1/20/2005 00:00 - 04:30 4.50 TIEBAC N DPRB OTHCMP Continue to RIH with 4.5" liner as per detailed running procedure. 04:30 - 05:30 1.00 TIEBAC N DPRB OTHCMP Chg elevators. PU liner hook hanger and running tool. Upwt 95K Dn wt 87K. 05:30 - 06:30 1.00 TIEBAC N DPRB OTHCMP Run 4.5" liner on Drill Pipe down to window. 100k up. 90k down. 06:30 - 07:00 0.50 TIEBAC N DPRB OTHCMP Position shoe at mid point of window. Rotate 3 turns to right. Exit window on first attempt. 07:00 - 13:30 6.50 TIEBAC N DPRB OTHCMP Run slotted liner in open hole. Clean to 10420'. From here to TD, took weight in multiple spots but able to PU and work thru each time. Acted as if centralisers or couplings were hanging up in the window. 13:30 - 14:15 0.75 TIEBAC N DPRB OTHCMP PU last single of DP. Work pipe & improve PU & SO wts. PU 18' above hook point. Put in 3/4 turn - no success. 1/2 turn. No success. 1/4 turn - no success. Run deeper past calculated hook point and get hanger hooked 15' deeper than calculated. 14:15 - 15:45 1.50 TIEBAC N DPRB OTHCMP Unhook & hook hanger at same depth x3. Rotate 1/4 turn and run past hook point. Rotate back 1/4 turn and hook x3. Unhook and rotate 1/2 turn. RIH - no hook. PU & rotate another 1/2 turn. RIH & land hook at same depth. Account for depth discrepancy in tally & verify hook depth is correct - OK. 15:45 - 16:30 0.75 TIEBAC N DPRB OTHCMP Load ball in drill pipe and pump down on seat. Pressure up to 2000 psi. PU &verify released from liner - OK. Continue pressuring up and shear ball seat at 3600 psi. Run back in and verify hanger is at same depth. 16:30 - 17:30 1.00 TIEBAC N DPRB OTHCMP POOH standing back Drill Collars to 5424', 17:30 - 18:30 1.00 TIEBAC N DPRB OTHCMP PJSM. Slip and cut drill line. 18:30 - 21 :30 3.00 TIEBAC N DPRB OTHCMP POOH (SLM). Lay down hanger running tool. Clear and clean rig floor. 21 :30 - 23:30 2.00 TIEBAC N DPRB OTHCMP PJSM. Rig up and pick up LEM #2 23:30 - 00:00 0.50 TIEBAC N DPRB OTHCMP Change out handling equipment and pick up & run inner string. 1/21/2005 00:00 - 02:30 2.50 TIEBAC N DPRB OTHCMP Pick up and run inner string inside LEM assembly. 02:30 - 03:00 0.50 TIEBAC N SFAL OTHCMP While making up first stand of drill pipe onto LEM assembly, a 1/2" bolt, 2-1/4" long with a 3/4" head broke off of the iron roughneck and fell past the slips into the hole. Drained the stack and looked for the bolt without success. 03:00 - 05:00 2.00 TIEBAC N SFAL OTHCMP Gather the rig team, fisherman, LEM tech and ANC staff to Printed: 2/7/2005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/21/2005 03:00 - 05:00 2.00 TIEBAC N SFAL OTHCMP discuss options with all parties. 05:00 - 06:00 1.00 TIEBAC N SFAL OTHCMP Bolt is now visible sitting in annular space between 7 5/8" casing and the liner top packer - laying sideways on tapered bore at top of wear ring. Call for magnet 1.75" OD. Will attempt to fish bolt out with this. Change plan as 1.75" magnet will be too big to go down to bolt. 06:00 - 09:30 3.50 TIEBAC N SFAL OTHCMP Use thin magnet from rig and attempt to retrieve bolt. Make several unsuccessful attempts. Change to mechanics magnet - stronger. Run in and retrieve bolt which appeared to be almost brand new. 09:30 - 16:00 6.50 TIEBAC N DPRB OTHCMP RIH with LEM package on drill pipe 16:00 - 17:30 1.50 TIEBAC N DPRB OTHCMP Land LEM on hanger while circulating through workstring when seal assembly is entering SBA. Pick up 15K over to verify LEM is latched into hook hanger. 17:30 - 18:30 1.00 TIEBAC P OTHCMP Drop ball and pump down to seat. Pressure up to 3200 psi to set ZXP packer and hold pressure for 5 minutes. Increase pressure to 4150 psi to release running tool. Bleed pressure to o psi. Close annular preventer and pressure test packer to 1500 psi for 10 minutes, good test. Pressure up drill pipe to 500 psi and pick up to observe pressure drop to 0 psi, OK. 18:30 - 22:30 4.00 TIEBAC P OTHCMP POOH with LEM running tools and inner string. 22:30 - 00:00 1.50 TIEBAC P OTHCMP Lay down running tools and inner string. 1/22/2005 00:00 - 01 :00 1.00 TIEBAC P OTHCMP Continue laying down LEM running equipment. 01 :00 - 02:00 1.00 TIEBAC P OTHCMP Rig down tubing equipment. Clean rig floor. 02:00 - 06:30 4.50 STWHIP P WEXIT PJSM. Pick up Whipstock assembly, MWD, drill collars and HWDP. Shallow test MWD. 06:30 - 10:30 4.00 STWHIP P WEXIT RIH with whipstock assembly, orient whipstock to 17L and set seals at 6063'. Set bottom anchor and shear off mills. 132K Up Wt. 107K Dn Wt. 10:30 - 12:15 1.75 STWHIP P WEXIT Displace SFOBM with warm (100 degrees) MOBM at 84 SPM, 1850 psi. Capture returned SFOBM into vac trucks for return to mud plant. 12:15 - 12:30 0.25 STWHIP P WEXIT Begin milling window. TOW at 5986'. 12:30 - 13:30 1.00 STWHIP P WEXIT Service rig and TDS. 13:30 - 15:30 2.00 STWHIP N RREP WEXIT Problem with TDS brake. Troubleshoot and repair. 15:30 - 20:30 5.00 STWHIP P WEXIT Resume milling operations. Mill window and 33' of formation to 6018'. TOW = 5986' BOW = 5998' 20:30 - 22:30 2.00 STWHIP P WEXIT Circulate bottoms up and pump a hi vis sweep around. Note-75 Ibs metal captured at surface during milling and circulating operations. 22:30 - 00:00 1.50 STWHIP P WEXIT POOH from 6018' to 5702'. 1/23/2005 00:00 - 02:00 2.00 STWHIP P WEXIT POOH from 5702' to BHA. 02:00 - 04:30 2.50 STWHIP P WEXIT Stand back HWDP and DC. Lay down milling BHA. 04:30 - 05:00 0.50 STWHIP P WEXIT Clean and clear rig floor. 05:00 - 06:30 1.50 BOPSUF P WEXIT Function and flush BOP stack. 06:30 - 08:30 2.00 STWHIP P WEXIT Pick up 6.75" drilling BHA. 08:30 - 09:30 1.00 STWHIP N RREP WEXIT Repair air valve on top drive. 09:30 - 10:30 1.00 STWHIP P WEXIT Continue PU BHA #27. PJSM & load nuclear source. 10:30 - 14:30 4.00 STWHIP P WEXIT RIH picking up singles drill pipe from shed. Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/23/2005 14:30 - 15:00 15:00 - 19:00 19:00 - 20:00 20:00 - 00:00 1/24/2005 00:00 - 12:00 12:00 - 00:00 1/25/2005 00:00 - 08:30 08:30 - 09:00 09:00 - 12:00 12:00 - 00:00 1/26/2005 00:00 - 12:00 12:00 - 00:00 1/27/2005 00:00 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 08:00 08:00 - 20:30 20:30 - 23:00 23:00 - 23:30 0.50 STWHIP P 4.00 STWHIP P 1.00 STWHIP P WEXIT WEXIT WEXIT 4.00 DRILL P PROD5 12.00 DRILL P PROD5 12.00 DRILL P PROD5 8.50 DRILL P 0.50 DRILL P 3.00 DRILL P PROD5 PROD5 PROD5 12.00 DRILL P PROD5 12.00 DRILL P PROD5 12.00 DRILL P PROD5 Shallow test MWD. RIH to above top of window at 5958'. Circulate to establish basline ECD. Orient BHA and pass through window. Directional drill 6.75" hole from 6018' to 6250'. PU wt 120K. SO Wt 105K. TVD 5137'. Directional drill 6.75" hole from 6250' to 7013'. UP wt 121K. Dn wt 92K. Rt wt 105K. TO on 5K. TO off 5K. ROT 80. WOB 2K. 332 GPM. 2750 psi. AST 5.28. ART .7. Directional drill 6.75" hole from 7013' to 7974'. UP wt 118K. Dn wt 93K. Rt wt 100K. TO on 5-6K. TO off 5-6K. ROT 80. WOB 4K. 332 GPM. 2750 psi. AST 3.6. ART 3.16. Calculated ECD = 10.00 to 10.10 Actual ECD = 10.4 to 10.52 Directional drill 6.75" hole from 7974' to 8874'. Circulate sweep around. Directional drill 6.75" hole from 8874' to 9030'. UP wt 123K. Dn wt 88K. Rt wt 105K. TO on 7K. TO off 6K. ROT 80. WOB 5K. 332 GPM. 3000 psi. AST .73. ART 3.27. Directional drill 6.75" hole from 9030' to 10,056'. UP wt 133K. Dn wt 91 K. Rt wt 107K. TO on 7K. TO off 6K. ROT 80. WOB 5K. 310 GPM. 3240 psi. AST 1.72. ART 3.31. Calculated ECD = 10.48 Actual ECD = 10.89 Continue drilling 6.75" hole 10,056' to 10,765' MD. 138 klbs up. 84 klbs down. 110 klbs rot. Torque: On btm 8 kit Ibs. Off btm 7 kit Ibs. 330 gpm @ 3380 psi. Continue drilling 6.75" hole from 10,765' MD to 11,592'. 145 klbs up. 78 klbs down. 110 klbs rot. Torque: On btm 8-9 kit Ibs. Off btm 7-8 kit Ibs. 330 gpm @ 3460 psi. Total for day - AST = 5.37 ART = 2.66 Calculated ECD = 10.61 Actual ECD = 10.80 PROD5 Continue drilling 6.75" hole from 11,592' to 11,943'. ECD at hardline. PROD5 CBU and sweep to clean hole and lower ECD PROD5 Continue drilling 6.75" hole from 11,943' to 12054'. Have difficulty sliding due to excessive drag. Decision made to TD hole at this point. AST = 1 .15 ART = .75 PROD5 Circulate and condition hole for short trip. PROD5 POOH backreaming from 12,054' to 6798'. Tight spot at 10,867'. Worked through, cleaned up. PROD5 POOH I MAD pass from 6798' to 6084'. 80 rpm, 70spm, 250 gpm, 1900 psi. Pull up above window. PROD5 Make up and set RTTS at 50'. 3.50 DRILL P 0.50 DRILL P 1.00 DRILL P 3.00 DRILL P 12.50 DRILL P 2.50 DRILL P 0.50 DRILL P Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 1/27/2005 23:30 - 00:00 0.50 DRILL P PROD5 Pull wear bushing. Set test plug. Rig up and test BOPE. Witness of test waived by AOGCC Rep Jeff Jones. 1/28/2005 00:00 - 08:00 8.00 CASE P PROD5 Continue test BOPE's tI 250 psi lowl 3,500 psi high. Witness of test waived by AOGCC Rep., Jeff Jones. Choke line HCR valve failed test. Top drive upper IBOP failed test. 08:00 - 00:00 16.00 CASE N RREP PROD5 Replace choke line HCR - OK. Replace failed upper IBOP. When making up, the box of the new one swelled. Remove same and re-build previous one. 1/29/2005 00:00 - 03:00 3.00 CASE N RREP PROD5 Continue repairs to IBOP. Complete & test same to 250/3500 psi - OK. 03:00 - 04:30 1.50 CASE P PROD5 Run in and retrieve storm packer and drillstring. Well static. LD RTTS. 04:30 - 09:30 5.00 CASE P PROD5 RIH to bottom - hole in good condition. Saw slight bobble at 10867' but went straight on thru. 09:30 - 12:00 2.50 CASE P PROD5 Break circ & stage pumps up to 290 gpm. Pump 20 bbllow vis sweep followed by 20 bbl weighted sweep surf to surf. 285 gpm @ 3280 psi. 80 rpm. 12:00 - 14:00 2.00 CASE P PROD5 Displace well to 9.2 ppg solids free MOBM. 285 gpm @ 3200 psi. 80 rpm. CBU X2 to condition & warm mud. 14:00 - 18:30 4.50 CASE P PROD5 Monitor well. Static. POH to window racking back DP. Hole in good condition - no tight spots. 18:30 - 21 :00 2.50 CASE P PROD5 Cont POH LDDP to 3800'. 21 :00 - 22:00 1.00 CASE P PROD5 Service top drive & replace bolts on grabber. 22:00 - 00:00 2.00 CASE P PROD5 Continue POH to 2700' LDDP. 1/30/2005 00:00 - 03:15 3.25 CASE P PROD5 Continue POH LDDP. 03:15 - 03:30 0.25 CASE P PROD5 PJSM for removing source from LWD tool. 03:30 - 06:30 3.00 CASE P PROD5 Remove RA source. LD BHA #27. Clear & clean rig floor. 06:30 - 08:00 1.50 WHIP P RUNPRD MU whipstock retrieval BHA. Orient and test MWD - OK. 08:00 - 11 :00 3.00 WHIP P RUNPRD RIH on 4" DP to recover whipstock. 11 :00 - 12:00 1.00 WHIP P RUNPRD Break circ & stage up to 300 gpm @ 1720 psi - 125k up, 102k down. Orient hook to 17L and engage hook into whipstock. Verify engaged. Pull 50 klbs over & let jars bleed off. Increase to 80 klbs over & release anchor - OK. 12:00 - 13:00 1.00 WHIP P RUNPRD CBU X2 - 300 gpm @ 1750 psi. Monitor well - static. Blow dn top drive. 13:00 - 16:00 3.00 WHIP P RUNPRD POH with whipstock. Rack back DP & HWDP. 16:00 - 18:30 2.50 WHIP P RUNPRD LD all whipstock retrieving tools & MWD. LD whipstock. 18:30 - 19:30 1.00 WHIP P RUNPRD Clear floor & clean drip pan under rotary table. 19:30 - 20:00 0.50 CASE P RUNPRD RU to run 4.5" liner 20:00 - 20:30 0.50 CASE P RUNPRD PJSM BPX, Doyon, Doyon Casing, MI. Run 4.5" liner. 20:30 - 00:00 3.50 CASE P RUNPRD Run 4.5" 12.6# L-80 IBTslotted liner. -80 jts in @ midnight. 1/31/2005 00:00 - 03:00 3.00 CASE P RUNPRD Continue running 4.5" slotted liner for L3 lateral. 127 jts slotted, swell packer, 9 solid, swell packer, 2 solid, hook hanger. 03:00 - 04:45 1.75 CASE P RUNPRD MU hanger to 4" DP. Run in 1 std + 60' to middle of window. Rotate 3 turns & RIH. Tag previous liner top. Pull out above window and apply 1/4 turn. Run in and tag liner top again. Repeat and on 5th 1/4 turn applied, exited window successfully. 04:45 - 12:30 7.75 CASE P RUNPRD Run liner into open hole on 4" DP to 11,735'. Saw no problems when running liner in open hole. 12:30 - 13:00 0.50 CASE P RUNPRD Get weights - 185 klbs up. 85 klbs dn. MU TD. RIH past hook point to 11812'. Printed: 2f712005 9:37:45 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: Rig Release: Rig Number: Spud Date: 12/29/2000 End: 2/3/2005 11/19/2004 2/3/2005 9ES 1/31/2005 12:30 - 13:00 0.50 CASE P RUNPRD PU 20' and apply 1/4 turn @ surface. Run in and engage hook hanger to put shoe at 11,804'. PU & apply 1/2 turn. Run past hook depth. PU & apply another 1/2 turn. RIH & engage hook. Repeat x 2. Hanger is hooked on depth. 13:00 - 13:30 0.50 CASE P RUNPRD Drop setting ball & pump on seat - 4 bpm @ 650 psi. Pressure up to 3500 psi & release from liner. PU & verify off liner, PI U Weight 132klbs - OK. PU 50'. 13:30 - 14:30 1.00 CASE P RUNPRD CBU x 2 above liner - 7 bpm @ 1,480 psi. Monitor well. Run in & tag liner on depth. Blow down top drive. 14:30 - 16:00 1.50 CASE P RUNPRD PJSM. Slip & cut drilling line. Service top drive. 16:00 - 19:00 3.00 CASE P RUNPRD POH with hook hanger running tool. 19:00 - 19:30 0.50 CASE P RUNPRD LD liner running tool. 19:30 - 20:00 0.50 CASE P RUNPRD Clear floor & clean under rotary table. 20:00 - 20:45 0.75 CASE P TIEB3 RU to run 4.5" LEM assembly #3. 20:45 - 21 :00 0.25 CASE P TIEB3 PJSM for running LEM. 21 :00 - 23:00 2.00 CASE P TIEB3 MU LEM assembly #3 With inner string & setting tool on 1 std 4" DP. 23:00 - 23:30 0.50 CASE P TIEB3 Remove Anadrill pressure sensor from standpipe and plug outlet. 23:30 - 00:00 0.50 CASE P TIEB3 RIH with LEM assembly on 4" DP. 2/1/2005 00:00 - 04:00 4.00 CASE P TIEB3 RIH wI LEM Assembly #3 on 4" DP to 5,980'. Established Parameters: String Weight Up 135,000#, String Weight Down 122,000#. 04:00 - 05:00 1.00 CASE P TIEB3 05:00 - 06:00 1.00 CASE P TIEB3 I 06:00 - 06:30 0.50 CASE P TIEB3 06:30 - 10:00 3.50 CASE P TIEB3 10:00 - 10:30 0.50 CASE P TIEB3 10:30 - 14:30 4.00 CASE P TIEB3 M I U Top Drive, Washed Down Through Top of Hook Hanger. Continued to Wash Down into PBR on L2 LEM. Tagged Up 8' High on First 2 Attempts, Applied 1/4 Turn x 2 and Landed LEM Assembly. PI U wI 15,000# Overpull to Verify LEM Collet in Place. Dropped Setting Ball and Pumped onto Seat; ICR 4 bpm, 500 psi, FCR 1bpm, 50 psi. Pressured Up to 4,000 psi to Release Running Tool and Set ZXP Liner Top Packer, Observed Good Indication on Surface of Packer Setting. Closed Upper Pipe Rams and Tested 7-5/8" and ZXP Packer to 1,500 psi f/15 Minutes, OK. Bled Down Pressure, Opened Rams. POOH w/3 Stands to 5,840'. Circulated to Condition Mud, Pump Rate 3 bpm, 500 psi. Waited on Brine Trucks. Held PJSM wI MI - Rig Crew - Truck Drivers - Tool Pusher- Drilling Supervisor. Displaced Wellbore to 9.3 ppg Brine; Pumped 25 bbls LVT from Pit #4, Shut Down to Clean Pit #4, Pumped 25 bbls 9.3 ppg Viscosified Brine - 50 bbls 9.3 ppg Brine w/1% Safe-Surf- 50 bbls 9.3 ppg Viscosified Brine - 300 bbls Clean 9.3 ppg Brine, Staged Up Pumps at the Following Rates: 3.5 bpm 600 psi 5.0 bpm 750 psi 6.0 bpm 1,100 psi Over Displaced By 50 bbls to Ensure Clean Well bore Fluid. Printed: 217/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/19/2004 2/3/2005 9ES Spud Date: 12/29/2000 End: 2/3/2005 2/1/2005 10:30 - 14:30 4.00 CASE P TIEB3 Monitored Well, Static. Blew Down Top Drive. 14:30 - 15:00 0.50 CASE P TIEB3 Serviced Rig 15:00 - 16:00 1.00 CASE N RREP TIEB3 Repaired Top Drive 16:00 - 23:30 7.50 CASE P TIEB3 POOH, LID 4" HWDP, 4-3/4" DC, 4" DP. 23:30 - 00:00 0.50 CASE P TIEB3 RIH wI excess Dp in derrick 2/2/2005 00:00 - 02:00 2.00 CASE P TIEB3 POOH & LI D DP 02:00 - 02:30 0.50 CASE P TIEB3 Clear'd & Clean'd Rig Floor Pull'd Wear Bushing 02:30 - 04:00 1.50 RUNCOrvP RUNCMP PJSM R I U I-Wire Spooler, Overhead Sheaves, Tbg. Tongs & Hand Tools 04:00 - 06:00 2.00 RUNCOrvP RUNCMP PJSM M I U 4-1/2" Tail Pipe: 4-1/2" Mule Shoe Assy wI 5.60" OD No-Go Locator - Lwr X Nipple Assy - Upper X Nipple Assy wI RHC-M Sleeve - 1 Jt 4-1/2" Tubing - 4-1/2" x 7 5/8" Premier Pkr - 7-5/8" Phoenix Jet Pump Gauge Assy - 4-1/2" Sliding Sleeve 7" Phoenix Discharge Pressure Gauge Assy. M I U and Tested I - Wire Connection. 06:00 - 14:00 8.00 RUNCOrvP RUNCMP M I U and RIH wI 4-1/2" 12.6# L-80 IBT-M Tubing. Average M I U Torque 3,250 ft Ilbs. M I U I - Wire Clamps to First 10 Joints, Then to Every Other Joint. Tested I - Wire Continuity Every 30 Joints. 14:00 - 15:00 1.00 RUNCOM'J HMAN RUNCMP Pinched I - Wire on Tubing Slips, Broke Metal Casing. Cut and Spliced I - Wire. Tested Continuity - OK. 15:00 - 17:00 2.00 RUNCOrvP RUNCMP M I U and RIH wI 4-1/2" 12.6# L-80 IBT-M Tubing. Average M I U Torque 3,250 ft Ilbs. M I U I - Wire Clamps to Every Other Joint. Tested I - Wire Continuity Every 10 Joints. 17:00 - 18:30 1.50 RUNCOrvP RUNCMP M I U Jts. #135, #136 for Tag Up on No-Go in Tieback. String Wt. Up 97K, Dn 92K Tagged Up @ 16.53' in on Jt. #136, obtain measurements for Space Out. U 0 Jts. #136, #135, & #134. PIU & M/U Space Out Pups 9.80',9.82',7.82'. P/U Jt. #134, Tbg. Hgr. & Ldg. Jt. 18:30 - 19:30 1.00 RUNCOrvP RUNCMP M/U I·Wire through Tbg. Hgr. and Test Integrety of fittings & Wire Continuity 19:30 - 20:00 0.50 RUNCOrvP RUNCMP RIH & Land Hgr. in Tbg. Spool, Check landing marks to insure proper land out & RILDS 20:00 - 21 :00 1.00 RUNCOrvP RUNCMP M/U Circ. Lines to 7 5/8" x 4 1/2" Annulus & Ldg. Jt. Pressure Test Lines t/4,000 psi. 21 :00 - 22:00 1.00 RUNCOrvP RUNCMP Reverse Circ. 100 bbls. Corrosion Inhibited 9.3 Brine Dn. 75/8" x 4 1/2" Annulus @ 3 bpm @ 200psi 22:00 - 00:00 2.00 RUNCOrvP RUNCMP Drop 1 7/8" BallI Rod Assy. & Pressure up on Tbg. t/ 4,200 psi. to Set the Pkr. (hold 5 min.). Bleed pressure down to 3,500 psi. to Test Tbg. (hold 30 min.). Bleed pressure down to 2,500 psi. & shut in same. Pressure up the 7 5/8" x 4 1/2" ann. to 3,500 psi. (hold 30 min.). Bled pressure off Tbg. (2,500 psi) & allow pressure on the IA (3,500psi.) to shear DCK Valve. Bleed off all excess pressure. To insure opening of the DCK Valve Rev. Circ. Dn IA @ 3 bpm @ 900 psi. & then Dn Tbg @ 3 bpm @ 875 psi. 2/3/2005 00:00 - 00:30 0.50 RUNCOMP RUNCMP Blow On. all Circ. Lines & RID same from IA & Ldg Jt. 00:30 - 01 :00 0.50 RUNCOrvP RUNCMP UD Ldg. Jt., Set TWC in Tbg. Hgr. & Test from below t/1,OOO psi. OK Printed: 2/7/2005 9:37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-213 S-213 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 11/19/2004 Rig Release: 2/3/2005 Rig Number: 9ES Spud Date: 12/29/2000 End: 2/3/2005 2/3/2005 01 :00 - 04:30 3.50 BOPSUPP OTHCMP PJSM NID BOPE, Remove Rotary Master Bushings & clean drip pan area. 04:30 - 08:30 4.00 WHSUR P OTHCMP PJSM N/U Adapter Flange & Tree, Tested Neck Seal & void V 5,000 psi. Good Test Test I-Wire Continuity- OK 08:30 - 09:00 0.50 WHSUR P OTHCMP R/U & Test Production Tree V 5,000 psi. Good Test, RID test lines. 09:00 - 10:00 1.00 WHSUR P OTHCMP R/U DSM & Pull'd TWC, RID DSM 10:00 - 11 :00 1.00 WHSUR P OTHCMP PJSM R/U Little Red t/7 5/8" x 4 1/2" IA. Pressure Test lines V 3,000psi. 11 :00 - 12:30 1.50 WHSUR P OTHCMP Pump 100 bbls Diesel Freeze Protect @ 2 bpm @ 1,000 psi. 12:30 - 14:00 1.50 WHSUR P OTHCMP U-Tube Diesel, 200 psi. on IA & Tbg. when done. Wellbore Fluid. Hydrostatic Pressure 2,132 psi. Formation Pressure 2,300 psi. 14:00 - 15:30 1.50 WHSUR P OTHCMP PJSM R/U DSM Lubricator, Set BPV., RID DSM. Tested BPV t/1 ,000 psi. from below. OK. Little Red sucked excess diesel from lines & RID same 15:30 - 17:00 1.50 WHSUR P OTHCMP RID Secondary IA Valve, DSM Installed VR Plugs 17:00 - 18:00 1.00 WHSUR P OTHCMP Secured Well, Clear & Clean Cellar area. 18:00 - 00:00 6.00 WHSUR P RUNCMP Clean MOBM fl Dp Drain Racks, Drip Pans, All under floor containments, Misc. Rig Components. Rig Released @ 2400 hrs. on 2-3-05 Printed: 2/7/2005 9:37:45 AM S-213A Survey Report hi umberger Report Date: 12/12/2004 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 196.54' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 11, E 0.000 11 Structure I Slot: S·PAD I S-213 TVD Reference Datum: Rotary Table Well: S·213 TVD Reference Elevation: 61.8211 relative to MSL Borehole: S-213A Sea Bed I Ground Level Elevation: 35.90 11 relative to MSL UWVAPI#: 500292299301 Magnetic Declination: 24.819' Survey Name I Date: S-213A I December 12, 2004 Total Field Strength: 57610.755 nT TortI AHD I DDII ERD ratio: 473.359' 18581.4911 16.973/1.628 Magnetic Dip: 80.845' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: December 06, 2004 . Location LatlLong: N 70.35551358, W 149.03415537 Magnetic Declination Model: BGGM 2004 Location Grid NlE YIX: N 5980549.840 I1US, E 618929.960 ftUS North Reference: True North Grid Convergence Angle: +0.90963906' Total Corr Mag North -> True North: +24.819' Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head I Comments Measured Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) ( ft) (It) (It) (deg/100 fI) (flUS) (flUS) Projected-Up 0.00 0.00 297.52 -61.82 0.00 -0.02 0.00 0.11 0.05 -0.10 0.00 5980549.89 618929.86 N 70.35551372 W 149.03415617 MWD+IFR:AK 155.42 0.08 297.52 93.60 155.42 -0.04 0.11 0.22 0.10 -0.20 0.05 5980549.94 618929.76 N 70.35551386 W 149.03415697 233.49 0.19 189.70 171.67 233.49 0.08 0.25 0.27 0.00 -0.27 0.29 5980549.84 618929.69 N 70.35551358 W 149.03415754 327.03 0.28 217.18 265.21 327.03 0.44 0.63 0.55 -0.33 -0.43 0.15 5980549.50 618929.53 N 70.35551266 W 149.03415888 415.75 0.46 188.45 353.93 415.75 1.00 1.19 1.06 -0.86 -0.62 0.29 5980548.97 618929.36 N 70.35551123 W 149.03416037 509.99 0.27 140.23 448.17 509.99 1.50 1.76 1.50 -1.40 -0.53 0.37 5980548.43 618929.45 N 70.35550974 W 149.03415966 602.31 0.35 136.82 540.48 602.30 1.76 2.26 1.79 -1.78 -0.20 0.09 5980548.06 618929.79 N 70.35550872 W 149.03415697 694.94 0.40 110.75 633.11 694.93 1.93 2.86 2.12 -2.10 0.30 0.19 5980547.75 618930.29 N 70.35550785 W 149.03415294 787.96 0.15 142.58 726.13 787.95 2.02 3.29 2.41 -2.31 0.68 0.31 5980547.54 618930.67 N 70.35550727 W 149.03414987 883.26 0.36 98.80 821.43 883.25 2.05 3.70 2.67 -2.45 1.05 0.29 5980547.40 618931.05 N 70.35550687 W 149.03414686 976.53 0.43 98.44 914.70 976.52 1.97 4.34 3.06 -2.55 1.68 0.08 5980547.32 618931.68 N 70.35550661 W 149.0.69 1069.16 0.53 98.28 1007.32 1069.14 1.86 5.12 3.62 -2.66 2.45 0.11 5980547.22 618932.45 N 70.35550630 W 149.0 46 1160.63 0.56 78.60 1098.79 1160.61 1.59 5.98 4.23 -2.64 3.31 0.21 5980547.26 618933.31 N 70.35550638 W 149.03412850 1253.35 0.77 70.45 1191.50 1253.32 1.01 7.05 4.93 -2.34 4.34 0.25 5980547.57 618934.34 N 70.35550719 W 149.03412013 1347.39 1.25 70.29 1285.53 1347.35 0.03 8.71 6.16 -1.78 5.90 0.51 5980548.15 618935.89 N 70.35550871 W 149.03410745 1439.53 1.80 76.02 1377.64 1439.46 -1.30 11.16 8.32 -1.09 8.25 0.62 5980548.88 618938.23 N 70.35551059 W 149.03408837 1534.40 1.41 74.91 1472.47 1534.29 -2.67 13.82 10.83 -0.43 10.82 0.41 5980549.58 618940.79 N 70.35551241 W 149.03406747 1630.00 0.74 66.98 1568.05 1629.87 -3.68 15.61 12.53 0.12 12.53 0.72 5980550.16 618942.48 N 70.35551390 W 149.03405364 1723.15 2.46 259.23 1661.18 1723.00 -3.15 17.31 11.12 -0.02 11.12 3.42 5980550.00 618941.08 N 70.35551353 W 149.03406509 1814.13 6.28 254.60 1751.88 1813.70 0.38 24.24 4.72 -1.71 4.40 4.21 5980548.20 618934.39 N 70.35550892 W 149.03411964 1863.71 6.40 256.71 1801.15 1862.97 3.19 29.71 3.19 -3.06 -0.90 0.53 5980546.76 618929.10 N 70.35550522 W 149.03416271 1907.37 6.39 253.07 1844.54 1906.36 5.74 34.58 7.07 -4.33 -5.60 0.93 5980545.42 618924.43 N 70.35550175 W 149.03420081 2000.61 6.09 240.31 1937.24 1999.06 12.18 44.67 17.01 -8.29 -14.86 1.52 5980541 .32 618915.24 N 70.35549093 W 149.03427601 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\S-213A\S-213A Generated 3/7/2005 1 :00 PM Page 1 of 7 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg) (It) ( It) (It) (It) (fI) ( It) (It) (deg/100 fI) (flUS) (flUS) 2095.16 5.63 239.01 2031.29 2093.11 19.22 54.32 26.66 -13.16 -23.19 0.51 5980536.31 618906.98 N 70.35547762 W 149.03434367 2187.42 5.36 237.61 2123.13 2184.95 25.81 63.16 35.49 -17.80 -30.71 0.33 5980531.56 618899.54 N 70.35546495 W 149.03440472 2282.02 5.13 235.24 2217.33 2279.15 32.44 71.80 44.13 -22.58 -37.91 0.33 5980526.66 618892.41 N 70.35545190 W 149.03446323 2375.30 7.07 239.64 2310.08 2371.90 39.88 81.71 54.03 -27.86 -46.29 2.14 5980521.25 618884.12 N 70.35543747 W 149.03453128 2469.73 12.17 244.54 2403.15 2464.97 50.80 97.48 69.77 -35.08 -60.31 5.47 5980513.81 618870.22 N 70.35541775 W 149.03464505 2503.22 14.39 244.19 2435.74 2497.56 55.96 105.17 77.44 -38.41 -67.24 6.63 5980510.37 618863.34 N 70.35540865 W 149.03470135 2532.82 15.76 243.38 2464.32 2526.14 61.19 112.87 85.12 -41.81 -74.14 4.68 5980506.86 618856.49 N 70.35539935 W 149.03475742 2562.81 17.56 242.48 2493.05 2554.87 67.12 121.46 93.71 -45.73 -81.80 6.06 5980502.82 618848.90 N 70.35538866 W 149.03481957 2591.90 19.43 241.38 2520.64 2582.46 73.60 130.69 102.94 -50.D7 -89.94 6.54 5980498.35 618840.84 N 70.35537678 W 149.03488567 2628.07 19.93 240.84 2554.70 2616.52 82.28 142.87 115.12 -55.96 -100.60 1.47 5980492.30 618830.27 N 70.35536070 W 149.03497226 2655.84 20.53 241.04 2580.75 2642.57 89.14 152.48 124.72 -60.62 -109.00 2.17 5980487.50 618821.95 N 70.35534796 W 149.0.2 2686.92 21.45 241.15 2609.77 2671.59 97.08 163.61 135.85 -66.00 -118.74 2.96 5980481.97 618812.29 N 70.35533326 W 149.0 5 2718.71 22.14 240.27 2639.29 2701.11 105.54 175.41 147.66 -71.78 -129.04 2.40 5980476.03 618802.09 N 70.35531748 W 149.03520313 2749.91 23.21 238.46 2668.08 2729.90 114.37 187.44 159.68 -77.91 -139.38 4.09 5980469.73 618791.84 N 70.35530073 W 149.03528714 MWD+IFR:AK 2798.38 24.47 236.38 2712.41 2774.23 129.18 207.03 179.24 -88.46 -155.88 3.12 5980458.92 618775.52 N 70.35527190 W 149.03542112 Tie-In Survey 2856.54 26.47 236.45 2764.92 2826.74 148.37 232.04 204.19 -102.30 -176.72 3.44 5980444.76 618754.90 N 70.35523410 W 149.03559029 Blind (Ine Trend) 2909.66 29.58 236.00 2811.80 2873.62 167.58 256.99 229.10 -116.18 -197.46 5.87 5980430.55 618734.39 N 70.35519619 W 149.03575870 Blind (Ine Trend) 3006.92 33.61 231.80 2894.64 2956.46 208.12 307.92 279.81 -146.26 -238.54 4.72 5980399.82 618693.80 N 70.35511399 W 149.03609224 First MWD+IFR+MS 3102.80 37.72 227.46 2972.53 3034.35 254.98 363.79 335.10 -182.53 -281.03 5.03 5980362.89 618651.89 N 70.35501492 W 149.03643724 3199.21 41.06 226.91 3047.03 3108.85 307.61 424.97 395.51 -224.11 -325.89 3.48 5980320.61 618607.70 N 70.35490132 W 149.03680152 3295.21 43.34 232.11 3118.17 3179.99 361.63 489.42 459.65 -265.90 -374.94 4.34 5980278.05 618559.32 N 70.35478715 W 149.03719974 3392.93 45.61 237.12 3187.91 3249.73 415.45 557.86 528.06 -305.46 -430.75 4.28 5980237.60 618504.15 N 70.35467904 W 149.03765290 3488.29 44.79 237.13 3255.11 3316.93 466.84 625.52 595.67 -342.19 -487.58 0.86 5980199.98 618447.92 N 70.35457870 W 149.03811430 3584.58 45.23 235.98 3323.18 3385.00 518.99 693.62 663.75 -379.73 -544.40 0.96 5980161.55 618391.71 N 70.35447615 W 149.03857564 3680.92 44.69 235.88 3391.35 3453.17 571.61 761.69 731.81 -417.86 -600.79 0.57 5980122.53 618335.93 N 70.35437195 W 149.03903347 3776.78 45.06 236.81 3459.28 3521.10 623.56 829.33 799.43 -455.34 -657.08 0.79 5980084.16 618280.24 N 70.35426955 W 149.03949057 3873.18 44.60 236.48 3527.65 3589.47 675.54 897.29 867.38 -492.71 -713.85 0.53 5980045.90 618224.08 N 70.35416745 W 149.03995146 3968.74 44.05 237.25 3596.01 3657.83 726.45 964.06 934.13 -529.21 -769.76 0.81 5980008.53 618168.76 N 70.35406773 W 149.0.0 4064.79 43.64 237.36 3665.29 3727.11 776.84 1030.60 1000.63 -565.15 -825.75 0.43 5979971.70 618113.35 N 70.35396952 W 149.0 9 4160.95 43.86 238.30 3734.75 3796.57 826.80 1097.09 1067.08 -600.55 -882.04 0.71 5979935.42 618057.64 N 70.35387279 W 149.04 697 4257.35 43.42 238.37 3804.51 3866.33 876.40 1163.62 1133.54 -635.47 -938.67 0.46 5979899.60 618001.58 N 70.35377736 W 149.04177668 4348.86 43.94 237.59 3870.69 3932.51 923.78 1226.82 1196.70 -668.98 -992.25 0.82 5979865.25 617948.54 N 70.35368580 W 149.04221170 4446.91 43.12 237.35 3941.78 4003.60 974.80 1294.35 1264.21 -705.30 -1049.18 0.85 5979828.04 617892.20 N 70.35358657 W 149.04267393 4545.83 44.42 236.52 4013.21 4075.03 1026.92 1362.77 1332.63 -742.64 -1106.53 1.44 5979789.80 617835.46 N 70.35348455 W 149.04313946 4641.52 44.65 236.80 4081 .42 4143.24 1078.24 1429.89 1399.74 -779.52 -1162.59 0.32 5979752.03 617779.99 N 70.35338376 W 149.04359463 4737.67 43.99 236.28 4150.21 4212.03 1129.69 1497.06 1466.91 -816.56 -1218.64 0.78 5979714.11 617724.54 N 70.35328255 W 149.04404961 4831.97 43.63 236.15 4218.26 4280.08 1179.94 1562.34 1532.19 -852.86 -1272.89 0.39 5979676.96 617670.88 N 70.35318336 W 149.04449008 4928.03 44.71 235.59 4287.16 4348.98 1231.71 1629.28 1599.13 -890.41 -1328.29 1.20 5979638.53 617616.08 N 70.35308073 W 149.04493984 5023.20 44.27 235.98 4355.06 4416.88 1283.37 1695.97 1665.82 -927.92 -1383.45 0.54 5979600.16 617561.54 N 70.35297825 W 149.04538755 5119.83 43.93 235.90 4424.45 4486.27 1335.33 1763.21 1733.06 -965.58 -1439.16 0.36 5979561.62 617506.44 N 70.35287533 W 149.04583980 5216.82 44.04 234.58 4494.24 4556.06 1387.89 1830.57 1800.41 -1003.98 -1494.49 0.95 5979522.35 617451.73 N 70.35277039 W 149.04628899 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\S-213A\S-213A Generated 3/7/2005 1 :00 PM Page 2 01 7 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg) (It) (It) (II) (II) (It) (II) (It) (deg/100 It) (IIUS) (ltUS) 5313.24 44.17 235.63 4563.47 4625.29 1440.36 1897.68 1867.50 -1042.37 -1549.53 0.77 5979483.10 617397.31 N 70.35266549 W 149.04673579 5409.71 43.74 235.73 4632.92 4694.74 1492.30 1964.63 1934.46 -1080.12 -1604.83 0.45 5979444.47 617342.62 N 70.35256232 W 149.04718470 5505.37 45.59 235.49 4700.95 4762.77 1544.50 2031.88 2001.70 -1118.10 -1660.32 1.94 5979405.62 617287.74 N 70.35245853 W 149.04763513 5602.48 48.31 234.89 4767.24 4829.06 1599.92 2102.83 2072.65 -1158.61 -1718.57 2.84 5979364.19 617230.14 N 70.35234781 W 149.04810801 5697.64 51.38 233.90 4828.60 4890.42 1657.35 2175.55 2145.34 -1200.96 -1777.69 3.32 5979320.91 617171.71 N 70.35223208 W 149.04858789 5793.44 54.39 235.09 4886.40 4948.22 1717.57 2251.94 2221.70 -1245.31 -1839.88 3.29 5979275.59 617110.24 N 70.35211089 W 149.04909269 5889.06 57.95 233.06 4939.63 5001 .45 1780.56 2331.35 2301.07 -1291.93 -1904.17 4.12 5979227.96 617046.70 N 70.35198349 W 149.04961454 5985.53 61.01 230.89 4988.62 5050.44 1848.27 2414.45 2383.97 -1343.13 -1969.60 3.72 5979175.73 616982.10 N 70.35184357 W 149.05014567 6079.45 65.32 228.53 5031.01 5092.83 1918.41 2498.23 2467.31 -1397.33 -2033.49 5.11 5979120.53 616919.09 N 70.35169545 W 149.05066419 6175.48 70.04 227.10 5067.47 5129.29 1994.32 2587.04 2555.34 -1456.98 -2099.28 5.10 5979059.84 616854.26 N 70.35153244 W 149.05119818 6270.97 73.80 224.33 5097.11 5158.93 2073.57 2677.80 2644.88 -1520.36 -2164.23 4.81 5978995.45 616790.33 N 70.35135924 W 149.0.31 6367.97 77.84 222.09 5120.87 5182.69 2157.59 2771.82 2737.00 -1588.90 -2228.59 4.73 5978925.90 616727.07 N 70.35117195 W 149.05 64 6461.21 79.51 218.49 5139.18 5201.00 2241 .26 2863.24 2825.69 -1658.62 -2287.69 4.19 5978855.25 616669.09 N 70.35098142 W 149.05272727 6555.03 79.70 217.97 5156.11 5217.93 2327.01 2955.52 2914.58 -1731.11 -2344.79 0.58 5978781.87 616613.15 N 70.35078334 W 149.05319067 6656.75 82.13 217.89 5172.17 5233.99 2420.53 3055.96 3011.43 -1810.33 -2406.53 2.39 5978701.69 616552.68 N 70.35056686 W 149.05369166 6751.71 81.21 217.48 5185.93 5247.75 2508.16 3149.91 3102.13 -1884.69 -2463.97 1.06 5978626.44 616496.43 N 70.35036367 W 149.05415774 6810.09 81.64 217.31 5194.63 5256.45 2562.10 3207.64 3157.87 -1930.55 -2499.03 0.79 5978580.03 616462.11 N 70.35023835 W 149.05444222 6945.77 87.98 217.84 5206.90 5268.72 2688.15 3342.70 3288.66 -2037.59 -2581.38 4.69 5978471.71 616381.47 N 70.34994586 W 149.05511050 6976.80 89.51 217.96 5207.58 5269.40 2717.05 3373.72 3318.80 -2062.07 -2600.44 4.95 5978446.93 616362.80 N 70.34987897 W 149.05526512 7009.30 90.09 217.29 5207.69 5269.51 2747.37 3406.22 3350.34 -2087.81 -2620.28 2.73 5978420.88 616343.38 N 70.34980863 W 149.05542611 7040.02 92.73 216.14 5206.94 5268.76 2776.19 3436.93 3380.05 -2112.42 -2638.64 9.37 5978395.98 616325.41 N 70.34974136 W 149.05557507 7073.77 95.31 214.11 5204.57 5266.39 2808.10 3470.59 3412.39 -2139.95 -2658.01 9.72 5978368.15 616306.49 N 70.34966613 W 149.05573222 7105.75 94.69 215.09 5201.78 5263.60 2838.39 3502.45 3442.94 -2166.18 -2676.10 3.62 5978341.64 616288.82 N 70.34959447 W 149.05587899 7136.68 93.93 211.99 5199.46 5261.28 2867.88 3533.29 3472.37 -2191.88 -2693.14 10.29 5978315.67 616272.19 N 70.34952424 W 149.05601723 7169.47 92.66 211.87 5197.57 5259.39 2899.44 3566.03 3503.35 -2219.66 -2710.45 3.89 5978287.62 616255.32 N 70.34944832 W 149.05615769 7201.16 92.56 210.72 5196.13 5257.95 2930.05 3597.68 3533.22 -2246.71 -2726.89 3.64 5978260.31 616239.31 N 70.34937440 W 149.05629110 7232.12 93.90 207.09 5194.39 5256.21 2960.24 3628.59 3561.98 -2273.77 -2741.83 12.48 5978233.03 616224.80 N 70.34930048 W 149.05641228 7264.98 94.31 204.05 5192.03 5253.85 2992.61 3661.37 3591.76 -2303.33 -2755.98 9.31 5978203.25 616211.13 N 70.34921970 W 149..01 7297.58 94.86 200.30 5189.43 5251.25 3024.94 3693.86 3620.50 -2333.42 -2768.24 11.59 5978172.97 616199.35 N 70.34913750 W 149. 47 7328.71 96.62 196.14 5186.31 5248.13 3055.89 3724.84 3646.89 -2362.83 -2777.92 14.45 5978143.41 616190.13 N 70.34905714 W 149.0 99 7361.45 97.04 191.74 5182.42 5244.24 3088.36 3757.34 3673.34 -2394.37 -2785.75 13.41 5978111.75 616182.81 N 70.34897096 W 149.05676845 7397.13 97.76 189.52 5177.82 5239.64 3123.55 3792.73 3701.02 -2429.14 -2792.28 6.49 5978076.89 616176.83 N 70.34887595 W 149.05682133 7424.69 97.69 192.23 5174.11 5235.93 3150.72 3820.04 3722.55 -2455.96 -2797.43 9.75 5978049.99 616172.11 N 70.34880269 W 149.05686307 7458.04 97.28 190.53 5169.77 5231.59 3183.65 3853.10 3748.89 -2488.38 -2803.96 5.20 5978017.48 616166.10 N 70.34871413 W 149.05691593 7490.69 96.34 189.30 5165.90 5227.72 3215.86 3885.52 3774.32 -2520.31 -2809.54 4.72 5977985.46 616161.02 N 70.34862688 W 149.05696114 7520.99 96.27 189.53 5162.57 5224.39 3245.74 3915.64 3797.87 -2550.02 -2814.46 0.79 5977955.68 616156.57 N 70.34854571 W 149.05700104 7554.64 95.14 191.26 5159.22 5221.04 3279.03 3949.12 3824.51 -2582.95 -2820.51 6.12 5977922.66 616151.05 N 70.34845573 W 149.05704998 7586.51 93.21 192.59 5156.90 5218.72 3310.71 3980.90 3850.40 -2614.05 -2827.07 7.35 5977891.47 616144.98 N 70.34837077 W 149.05710319 7616.46 93.28 189.18 5155.21 5217.03 3340.46 4010.81 3874.52 -2643.41 -2832.72 11.37 5977862.02 616139.80 N 70.34829056 W 149.05714893 7651.28 94.21 189.12 5152.93 5214.75 3374.92 4045.55 3902.02 -2677. 71 -2838.25 2.68 5977827.64 616134.82 N 70.34819684 W 149.05719368 7683.22 94.62 187.30 5150.48 5212.30 3406.43 4077 .40 3927.01 -2709.23 -2842.79 5.82 5977796.06 616130.78 N 70.34811073 W 149.05723049 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\S-213A\S-213A Generated 3/7/2005 1 :00 PM Page 3 of 7 Com ments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg) ( It) (It) (It) (It) (It) (It) (It) (deg/100 It) (ltUS) (ltUS) 7712.72 93.97 l84.81 5148.27 5210.09 3435.35 4106.81 3949.48 -2738.48 -2845.90 8.70 5977766.76 616128.14 N 70.34803082 W 149.05725558 7746.50 93.25 183.38 5146.14 5207.96 3468.27 4140.53 3974.60 -2772.11 -2848.30 4.73 5977733.11 616126.27 N 70.34793895 W 149.05727502 7779.09 92.90 188.09 5144.39 5206.21 3500.23 4173.07 3999.56 -2804.48 -2851.55 14.47 5977700.69 616123.53 N 70.34785052 W 149.05730131 7808.86 93.18 185.36 5142.81 5204.63 3529.52 4202.80 4022.78 -2834.00 -2855.03 9.21 5977671.12 616120.52 N 70.34776987 W 149.05732947 7843.78 93.35 183.78 5140.82 5202.64 3563.62 4237.66 4049.30 -2868.75 -2857.81 4.54 5977636.33 616118.29 N 70.34767492 W 149.05735191 7875.23 93.49 187.64 5138.94 5200.76 3594.45 4269.05 4073.68 -2899.98 -2860.94 12.26 5977605.06 616115.67 N 70.34758960 W 149.05737716 7906.37 91.36 186.76 5137.63 5199.45 3625.15 4300.16 4098.43 -2930.85 -2864.83 7.40 5977574.14 616112.26 N 70.34750527 W 149.05740871 7938.57 89.34 185.78 5137.43 5199.25 3656.83 4332.36 4123.82 -2962.85 -2868.35 6.97 5977542.08 616109.25 N 70.34741784 W 149.05743716 7969.00 89.82 182.29 5137.65 5199.47 3686.53 4362.79 4147.16 -2993.20 -2870.49 11.58 5977511.71 616107.59 N 70.34733492 W 149.05745444 8001.89 90.64 181.69 5137.52 5199.34 3718.37 4395.68 4171.74 -3026.07 -2871.63 3.09 5977478.83 616106.97 N 70.34724512 W 149.05746361 8034.59 91.02 185.42 5137.05 5198.87 3750.22 4428.38 4196.85 -3058.70 -2873.66 11.46 5977446.17 616105.46 N 70.34715599 W 149.0.6 8065.97 91.22 181.84 5136.43 5198.25 3780.80 4459.75 4221.07 -3090.00 -2875.65 11.42 5977414.84 616103.97 N 70.34707046 W 149.05 98 8097.79 90.54 184.08 5135.95 5197.77 3811.72 4491.57 4245.50 -3121.78 -2877.29 7.36 5977383.05 616102.84 N 70.34698366 W 149.05750922 8130.33 88.31 185.41 5136.27 5198.09 3843.57 4524.10 4271.21 -3154.20 -2879.98 7.98 5977350.59 616100.66 N 70.34689508 W 149.05753096 8161.64 87.35 185.47 5137.46 5199.28 3874.27 4555.39 4296.26 -3185.35 -2882.95 3.07 5977319.40 616098.19 N 70.34680999 W 149.05755494 8193.93 88.79 183.80 5138.55 5200.37 3905.85 4587.66 4321.90 -3217.51 -2885.55 6.83 5977287.21 616096.09 N 70.34672211 W 149.05757600 8226.32 88.65 184.52 5139.27 5201.09 3937.48 4620.04 4347.55 -3249.81 -2887.90 2.26 5977254.88 616094.26 N 70.34663388 W 149.05759496 8256.93 88.38 184.88 5140.06 5201.88 3967.42 4650.64 4372.05 -3280.30 -2890.41 1.47 5977224.35 616092.23 N 70.34655056 W 149.05761522 8289.45 88.65 185.12 5140.90 5202.72 3999.28 4683.15 4398.27 -3312.69 -2893.24 1.11 5977191.93 616089.92 N 70.34646209 W 149.05763811 8321 .57 89.13 186.90 5141.53 5203.35 4030.85 4715.27 4424.57 -3344.63 -2896.61 5.74 5977159.94 616087.06 N 70.34637484 W 149.05766530 8353.11 88.55 187.55 5142.17 5203.99 4061.97 4746.80 4450.85 -3375.91 -2900.57 2.76 5977128.60 616083.59 N 70.34628937 W 149.05769739 8385.72 89.61 187.18 5142.69 5204.51 4094.15 4779.40 4478.14 -3408.24 -2904.75 3.44 5977096.21 616079.93 N 70.34620103 W 149.05773121 8417.71 90.47 188.33 5142.67 5204.49 4125.77 4811.39 4505.09 -3439.94 -2909.07 4.49 5977064.45 616076.11 N 70.34611443 W 149.05776615 8449.35 90.54 186.84 5142.39 5204.21 4157.02 4843.03 4531 .77 -3471.30 -2913.24 4.71 5977033.03 616072.44 N 70.34602875 W 149.05779994 8481.45 91.46 183.78 5141.83 5203.65 4188.50 . 4875.13 4558.19 -3503.25 -2916.21 9.95 5977001.04 616069.97 N 70.34594145 W 149.05782395 8513.48 91.87 187.07 5140.90 5202.72 4219.91 4907.14 4584.66 -3535.12 -2919.24 10.35 5976969.12 616067.45 N 70.34585439 W 149.05784841 8545.26 91.12 185.20 5140.07 5201.89 4251.15 4938.91 4611.20 -3566.71 -2922.64 6.34 5976937.49 616064.56 N 70.34576810 W 149.05787586 8577.81 89.95 186.18 5139.76 5201.58 4283.12 4971.46 4638.34 -3599.10 -2925.86 4.69 5976905.06 616061.85 N 70.34567961 W 149..95 8610.07 90.06 183.67 5139.76 5201.58 4314.72 5003.72 4665.06 -3631.23 -2928.63 7.79 5976872.89 616059.59 N 70.34559181 W 149. 32 8641.85 90.78 184.52 5139.53 5201.35 4345.75 5035.50 4691.19 -3662.93 -2930.90 3.51 5976841.16 616057.83 N 70.34550521 W 149.0 64 8673.97 90.91 186.55 5139.05 5200.87 4377.27 5067.62 4718.12 -3694.90 -2934.00 6.33 5976809.15 616055.24 N 70.34541788 W 149.05796768 8706.18 90.98 184.16 5138.52 5200.34 4408.86 5099.82 4745.13 -3726.96 -2937.00 7.42 5976777.05 616052.74 N 70.34533029 W 149.05799197 8738.14 91.98 184.51 5137.70 5199.52 4440.09 5131.77 4771.68 -3758.82 -2939.42 3.31 5976745.16 616050.83 N 70.34524325 W 149.05801147 8771.07 93.66 187.04 5136.08 5197.90 4472.40 5164.66 4799.52 -3791.54 -2942.73 9.21 5976712.39 616048.04 N 70.34515386 W 149.05803821 8803.65 93.01 187.94 5134.18 5196.00 4504.52 5197.19 4827.62 -3823.78 -2946.97 3.40 5976680.09 616044.32 N 70.34506576 W 149.05807252 8834.93 92.66 184.75 5132.63 5194.45 4535.26 5228.43 4854.35 -3854.83 -2950.42 10.25 5976648.99 616041.36 N 70.34498094 W 149.05810044 8865.08 92.36 186.14 5131.31 5193.13 4564.82 5258.55 4879.92 -3884.81 -2953.28 4.71 5976618.97 616038.98 N 70.34489903 W 149.05812354 8899.41 90.78 184.81 5130.37 5192.19 4598.50 5292.86 4909.13 -3918.97 -2956.55 6.01 5976584.76 616036.25 N 70.34480570 W 149.05815000 8931.45 90.64 186.83 5129.98 5191.80 4629.97 5324.90 4936.56 -3950.84 -2959.80 6.32 5976552.85 616033.50 N 70.34471863 W 149.05817626 8962.45 90.81 188.48 5129.58 5191.40 4660.60 5355.90 4963.64 -3981.56 -2963.93 5.35 5976522.07 616029.86 N 70.34463470 W 149.05820967 SurveyEditor Ver 3.1 RT -SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\S-213A\S-213A Generated 3/7/2005 1 :00 PM Page 4 of 7 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (II) (deg) (deg) (II) (It) (II) (II) (II) (II) (II) (deg/100 II) (IIUS) (IIUS) 8996.97 89.85 187.15 5129.38 5191.20 4694.72 5390.42 4993.90 -4015.76 -2968.62 4.75 5976487.81 616025.71 N 70.34454127 W 149.05824765 9026.75 89.47 185.30 5129.56 5191.38 4724.01 5420.20 5019.65 -4045.36 -2971.85 6.34 5976458.16 616022.95 N 70.34446040 W 149.05827376 9058.08 89.54 183.62 5129.83 5191.65 4754.65 5451.53 5046.29 -4076.60 -2974.29 5.37 5976426.89 616021.01 N 70.34437507 W 149.05829343 9091.47 89.24 186.19 5130.19 5192.01 4787.35 5484.91 5074.87 -4109.86 -2977.14 7.75 5976393.59 616018.69 N 70.34428420 W 149.05831649 9123.55 89.54 185.42 5130.53 5192.35 4818.86 5516.99 5102.65 -4141.77 -2980.39 2.58 5976361.63 616015.95 N 70.34419701 W 149.05834272 9153.20 89.78 185.41 5130.71 5192.53 4847.95 5546.64 5128.26 -4171.29 -2983.19 0.81 5976332.08 616013.62 N 70.34411637 W 149.05836533 9186.04 89.82 185.80 5130.82 5192.64 4880.20 5579.48 5156.74 -4203.97 -2986.39 1.19 5976299.35 616010.93 N 70.34402708 W 149.05839125 9220.52 89.61 186.52 5130.99 5192.81 4914.11 5613.96 5186.85 -4238.25 -2990.09 2.18 5976265.02 616007.78 N 70.34393342 W 149.05842117 9249.91 88.93 186.22 5131.37 5193.19 4943.04 5643.35 5212.62 -4267.46 -2993.35 2.53 5976235.77 616004.98 N 70.34385363 W 149.05844753 9282.10 88.34 183.92 5132.13 5193.95 4974.57 5675.53 5240.51 -4299.51 -2996.20 7.37 5976203.68 616002.65 N 70.34376606 W 149.05847051 9314.67 87.38 184.98 5133.35 5195.17 5006.40 5708.08 5268.61 -4331.96 -2998.72 4.39 5976171.20 616000.64 N 70.34367741 W 149.0.9 9345.63 87.31 181.67 5134.78 5196.60 5036.50 5739.00 5295.03 -4362.83 -3000.52 10.68 5976140.30 615999.34 N 70.34359308 W 149.0 5 9379.10 87.32 183.63 5136.35 5198.17 5068.96 5772.44 5323.46 -4396.23 -3002.06 5.85 5976106.89 615998.32 N 70.34350184 W 149.05 78 9410.58 87.45 182.97 5137.79 5199.61 5099.57 5803.88 5350.43 -4427.62 -3003.87 2.13 5976075.47 615997.01 N 70.34341607 W 149.05853237 9442.20 88.27 184.66 5138.97 5200.79 5130.39 5835.48 5377.72 -4459.15 -3005.97 5.94 5976043.92 615995.41 N 70.34332994 W 149.05854933 9475.15 88.96 183.10 5139.77 5201.59 5162.53 5868.42 5406.24 -4492.01 -3008.20 5.18 5976011.03 615993.70 N 70.34324016 W 149.05856731 9507.89 88.00 184.30 5140.63 5202.45 5194.44 5901.15 5434.58 -4524.67 -3010.31 4.69 5975978.34 615992.11 N 70.34315093 W 149.05858434 9538.29 88.86 186.01 5141.47 5203.29 5224.23 5931.54 5461.31 -4554.94 -3013.04 6.29 5975948.04 615989.86 N 70.34306825 W 149.05860640 9571.34 89.54 185.82 5141.93 5203.75 5256.71 5964.58 5490.62 -4587.81 -3016.45 2.14 5975915.12 615986.98 N 70.34297845 W 149.05863393 9603.61 87.97 184.52 5142.63 5204.45 5288.33 5996.85 5519.09 -4619.94 -3019.36 6.32 5975882.95 615984.58 N 70.34289067 W 149.05865742 9633.58 88.52 181.48 5143.55 5205.37 5317.45 6026.80 5545.00 -4649.85 -3020.92 10.30 5975853.02 615983.49 N 70.34280895 W 149.05867004 9667.64 88.24 185.76 5144.51 5206.33 5350.63 6060.85 5574.69 -4683.82 -3023.07 12.59 5975819.03 615981.88 N 70.34271615 W 149.05868737 9698.72 89.10 185.45 5145.23 5207.05 5381.14 6091.92 5602.33 -4714.74 -3026.11 2.94 5975788.06 615979.34 N 70.34263166 W 149.05871189 9729.92 89.85 183.26 5145.52 5207.34 5411.63 6123.12 5629.81 -4745.85 -3028.48 7.42 5975756.93 615977.46 N 70.34254668 W 149.05873101 9765.67 90.33 182.31 5145.46 5207.28 5446.35 6158.87 5660.87 -4781.55 -3030.21 2.98 5975721.20 615976.29 N 70.34244913 W 149.05874499 9796.46 89.82 184.02 5145.42 5207.24 5476.31 6189.66 5687.77 -4812.30 -3031.91 5.80 5975690.44 615975.08 N 70.34236514 W 149.05875868 9828.53 88.86 182.80 5145.79 5207.61 5507.54 6221.72 5715.89 -4844.31 -3033.82 4.84 5975658.40 615973.68 N 70.34227769 W 149.05877406 9860.43 87.32 181.63 5146.85 5208.67 5538.43 6253.61 5743.56 -4876.16 -3035.05 6.06 5975626.53 615972.95 N 70.34219066 W 149.05878395 9892.46 88.34 178.61 5148.07 5209.89 5569.12 6285.61 5770.79 -4908.17 -3035.12 9.95 5975594.54 615973.40 N 70.34210323 W 149..39 9925.34 88.69 180.05 5148.92 5210.74 5600.52 6318.48 5798.57 -4941.03 -3034.74 4.51 5975561.68 615974.30 N 70.34201345 W 149. 16 9955.86 89.10 177.17 5149.51 5211.33 5629.55 6349.00 5824.20 -4971.53 -3034.00 9.53 5975531.20 615975.53 N 70.34193012 W 149.05877505 9988.03 89.20 181.28 5149.99 5211.81 5660.25 6381.16 5851 .44 -5003.69 -3033.56 12.78 5975499.06 615976.47 N 70.34184227 W 149.05877142 1 0020.48 88.48 179.27 5150.64 5212.46 5691 .40 6413.61 5879.29 -5036.13 -3033.72 6.58 5975466.62 615976.83 N 70.34175364 W 149.05877257 10052.71 89.37 178.65 5151.25 5213.07 5722.11 6445.83 5906.61 -5068.35 -3033.13 3.37 5975434.42 615977.93 N 70.34166563 W 149.05876772 10084.38 91.46 178.22 5151.02 5212.84 5752.21 6477.50 5933.35 -5100.00 -3032.27 6.74 5975402.78 615979.29 N 70.34157915 W 149.05876060 10116.55 92.08 178.39 5150.02 5211.84 5782.75 6509.65 5960.52 -5132.15 -3031.32 2.00 5975370.66 615980.75 N 70.34149134 W 149.05875278 10148.54 92.15 180.40 5148.84 5210.66 5813.30 6541.62 5987.89 -5164.11 -3030.98 6.28 5975338.71 615981.60 N 70.34140402 W 149.05874993 10180.37 92.08 180.54 5147.67 5209.49 5843.86 6573.43 6015.48 -5195.92 -3031.24 0.49 5975306.91 615981.84 N 70.34131712 W 149.05875194 10211.67 92.70 177.95 5146.36 5208.18 5873.72 6604.70 6042.30 -5227.18 -3030.83 8.50 5975275.65 615982.75 N 70.34123170 W 149.05874850 10243.39 91.74 182.62 5145.13 5206.95 5904.14 6636.40 6069.81 -5258.87 -3030.99 15.02 5975243.97 615983.10 N 70.34114514 W 149.05874968 10275.20 90.61 179.64 5144.48 5206.30 5934.80 6668.20 6097.69 -5290.66 -3031.61 10.02 5975212.17 615982.97 N 70.34105828 W 149.05875466 SurveyEditor Ver 3.1RT-SP3.03-HF5.00 Bld( d031rt-546) S-213\S-213\S-213A\S-213A Generated 3/7/2005 1 :00 PM Page 5 of 7 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (II) (deg) (deg) (II) (II) (II) (II) (II) (II) (II) (deg/100 II) (IIUS) (IIUS) 10307.76 88.28 181.20 5144.80 5206.62 5966.07 6700.75 6126.07 -5323.22 -3031.85 8.61 5975179.62 615983.25 N 70.34096935 W 149.05875649 10338.68 87.55 178.97 5145.92 5207.74 5995.70 6731.65 6152.96 -5354.12 -3031.90 7.58 5975148.73 615983.70 N 70.34088494 W 149.05875676 10371.26 88.34 177.65 5147.09 5208.91 6026.63 6764.21 6180.83 -5386.66 -3030.94 4.72 5975116.21 615985.17 N 70.34079603 W 149.05874886 10401.85 88.21 178.90 5148.01 5209.83 6055.66 6794.79 6207.04 -5417.22 -3030.02 4.11 5975085.67 615986.58 N 70.34071254 W 149.05874129 10434.75 87.11 176.76 5149.35 5211.17 6086.80 6827.66 6235.12 -5450.07 -3028.77 7.31 5975052.85 615988.34 N 70.34062281 W 149.05873109 10466.54 87.04 175.75 5150.98 5212.80 6116.58 6859.41 6261.83 -5481.75 -3026.70 3.18 5975021.21 615990.92 N 70.34053626 W 149.05871416 10499.01 87.35 173.12 5152.57 5214.39 6146.62 6891 .84 6288.59 -5514.02 -3023.55 8.15 5974988.99 615994.58 N 70.34044809 W 149.05868853 10531.42 87.38 169.78 5154.06 5215.88 6175.94 6924.22 6314.37 -5546.04 -3018.74 10.29 5974957.06 615999.90 N 70.34036065 W 149.05864938 10563.56 87.35 170.46 5155.53 5217.35 6204.69 6956.32 6339.55 -5577.66 -3013.23 2.12 5974925.53 616005.91 N 70.34027424 W 149.05860458 10596.09 87.62 167.52 5156.96 5218.78 6233.50 6988.82 6364.70 -5609.56 -3007.03 9.07 5974893.73 616012.62 N 70.34018711 W 149.05855412 10627.42 86.94 168.19 5158.45 5220.27 6260.95 7020.12 6388.58 -5640.16 -3000.44 3.05 5974863.25 616019.69 N 70.34010354 W 149.0.9 10659.90 87.04 166.77 5160.15 5221.97 6289.30 7052.55 6413.27 -5671.82 -2993.41 4.38 5974831.71 616027.22 N 70.34001704 W 149.0 4 10692.13 90.95 166.28 5160.72 5222.54 6317.20 7084.77 6437.51 -5703.15 -2985.90 12.23 5974800.50 616035.22 N 70.33993146 W 149.05 42 10724.10 92.98 168.36 5159.62 5221.44 6345.08 7116.72 6461.90 -5734.32 -2978.89 9.09 5974769.45 616042.73 N 70.33984632 W 149.05832542 10755.88 92.85 166.96 5158.01 5219.83 6372.88 7148.46 6486.32 -5765.32 -2972.11 4.42 5974738.56 616050.00 N 70.33976162 W 149.05827029 10788.42 92.40 165.81 5156.52 5218.34 6400.98 7180.96 6510.93 -5796.92 -2964.46 3.79 5974707.09 616058.15 N 70.33967532 W 149.05820810 10820.36 92.71 159.92 5155.09 5216.91 6427.52 7212.87 6533.83 -5827.39 -2955.06 18.45 5974676.77 616068.03 N 70.33959207 W 149.05813176 10852.35 92.61 159.56 5153.61 5215.43 6453.11 7244.83 6555.60 -5857.37 -2943.99 1.17 5974646.98 616079.57 N 70.33951018 W 149.05804188 10884.67 91.85 157.12 5152.35 5214.17 6478.49 7277.12 6577.11 -5887.38 -2932.07 7.90 5974617.16 616091.96 N 70.33942820 W 149.05794508 10916.59 91.92 155.73 5151.30 5213.12 6502.89 7309.03 6597.64 -5916.62 -2919.32 4.36 5974588.13 616105.18 N 70.33934834 W 149.05784146 10948.69 91.20 156.06 5150.42 5212.24 6527.23 7341.11 6618.15 -5945.91 -2906.21 2.47 5974559.05 616118.75 N 70.33926833 W 149.05773504 10979.35 92.20 156.76 5149.52 5211.34 6550.66 7371.76 6638.04 -5974.00 -2893.95 3.98 5974531.17 616131.46 N 70.33919162 W 149.05763545 Last MWD+IFR+MS 11012.52 90.75 156.32 5148.66 5210.48 6576.06 7404.92 6659.71 -6004.42 -2880.75 4.57 5974500.97 616145.14 N 70.33910854 W 149.05752825 First MWD+IFR:AK 11044.83 89.90 146.04 5148.48 5210.30 6598.74 7437.23 6678.52 -6032.69 -2865.19 31.92 5974472.95 616161.14 N 70.33903132 W 149.05740196 11075.11 90.00 144.27 5148.50 5210.32 6617.63 7467.51 6693.60 -6057.54 -2847.89 5.85 5974448.38 616178.83 N 70.33896345 W 149.05726152 11108.58 89.35 140.38 5148.69 5210.51 6637.20 7500.98 6708.93 -6084.02 -2827.44 11.78 5974422.23 616199.70 N 70.33889112 W 149.05709550 11140.86 89.25 142.93 5149.09 5210.91 6655.77 7533.25 6723.51 -6109.33 -2807.42 7.91 5974397.24 616220.12 N 70.33882199 W 149.05693297 11171.12 89.31 141.62 5149.47 5211.29 6673.44 7563.51 6737.58 -6133.27 -2788.90 4.33 5974373.60 616239.01 N 70.33875663 W 149.05678269 11204.88 89.49 143.49 5149.82 5211.64 6693.29 7597.27 6753.54 -6160.07 -2768.38 5.56 5974347.13 616259.95 N 70.33868343 W 149.~.09 11236.60 89.49 141.05 5150.10 5211.92 6711.81 7628.99 6768.52 -6185.15 -2748.97 7.69 5974322.36 616279.76 N 70.33861492 W 149.0 55 11267.19 89.97 133.95 5150.25 5212.07 6727.53 7659.58 6780.79 -6207.69 -2728.32 23.26 5974300.16 616300.76 N 70.33855337 W 149.05629092 11300.64 89.45 131.96 5150.42 5212.24 6742.41 7693.03 6791.88 -6230.48 -2703.84 6.15 5974277.76 616325.60 N 70.33849113 W 149.05609224 11332.38 89.14 129.93 5150.81 5212.63 6755.53 7724.76 6801 .48 -6251.28 -2679.87 6.47 5974257.35 616349.90 N 70.33843433 W 149.05589769 11363.18 88.90 130.17 5151.34 5213.16 6767.81 7755.56 6810.47 -6271.09 -2656.29 1.10 5974237.91 616373.78 N 70.33838022 W 149.05570638 11396.54 89.04 133.37 5151.94 5213.76 6782.03 7788.92 6821.30 -6293.31 -2631.42 9.60 5974216.09 616399.00 N 70.33831955 W 149.05550451 11428.43 89.07 133.78 5152.46 5214.28 6796.52 7820.80 6832.73 -6315.29 -2608.32 1.29 5974194.48 616422.44 N 70.33825953 W 149.05531703 11458.92 88.90 132.68 5153.00 5214.82 6810.21 7851.29 6843.61 -6336.17 -2586.11 3.65 5974173.96 616444.98 N 70.33820251 W 149.05513677 11492.51 89.21 133.64 5153.56 5215.38 6825.26 7884.87 6855.69 -6359.14 -2561.61 3.00 5974151.38 616469.84 N 70.33813977 W 149.05493795 11524.40 89.76 135.86 5153.84 5215.66 6840.33 7916.76 6868.12 -6381.59 -2538.96 7.17 5974129.30 616492.84 N 70.33807847 W 149.05475416 11554.63 88.63 136.77 5154.27 5216.09 6855.34 7946.99 6880.76 -6403.45 -2518.09 4.80 5974107.78 616514.06 N 70.33801877 W 149.05458472 11587.04 88.42 140.44 5155.10 5216.92 6872.54 7979.39 6895.60 -6427.75 -2496.67 11.34 5974083.82 616535.86 N 70.33795240 W 149.05441087 SurveyEditor Ver 3.1 RT -SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\S-213A \S-213A Generated 3m2005 1 :00 PM Page 6 of 7 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (II) (deg) (deg) (II) (II) (II) (II) (II) (It) (II) (deg/100 II) (IIUS) (IIUS) 11619.52 87.84 136.77 5156.16 5217.98 6889.77 8011.85 6910.59 -6452.10 -2475.20 11.43 5974059.82 616557.70 N 70.33788591 W 149.05423669 11649.97 87.77 136.73 5157.33 5219.15 6905.08 8042.28 6923.87 -6474.26 -2454.36 0.26 5974037.99 616578.90 N 70.33782538 W 149.05406748 11684.36 87.50 142.83 5158.75 5220.57 6923.91 8076.64 6940.59 -6500.49 -2432.18 17.74 5974012.12 616601.49 N 70.33775375 W 149.05388749 11716.33 88.87 142.63 5159.76 5221.58 6942.77 8108.59 6957.68 -6525.91 -2412.83 4.33 5973987.01 616621.24 N 70.33768431 W 149.05373044 11747.93 90.51 138.81 5159.93 5221.75 6960.52 8140.19 6973.73 -6550.37 -2392.83 13.16 5973962.88 616641.62 N 70.33761752 W 149.05356810 11778.98 90.24 139.03 5159.73 5221.55 6977.15 8171.24 6988.77 -6573.77 -2372.42 1.12 5973939.80 616662.39 N 70.33755359 W 149.05340251 11811.12 89.59 139.11 5159.78 5221.60 6994.43 8203.38 7004.52 -6598.05 -2351.37 2.04 5973915.86 616683.83 N 70.33748728 W 149.05323163 11843.68 89.79 137.99 5159.95 5221.77 7011.69 8235.94 7020.33 -6622.46 -2329.82 3.49 5973891.80 616705.76 N 70.33742062 W 149.05305671 11875.78 89.79 138.42 5160.07 5221.89 7028.54 8268.04 7035.86 -6646.39 -2308.42 1.34 5973868.21 616727.53 N 70.33735526 W 149.05288309 11907.58 90.51 137.15 5159.99 5221.81 7045.04 8299.84 7051.15 -6669.94 -2287.06 4.59 5973845.01 616749.27 N 70.33729094 W 149.05270969 11940.29 89.21 141.07 5160.07 5221.89 7062.64 8332.55 7067.65 -6694.66 -2265.65 12.63 5973820.63 616771.06 N 70.33722342 W 149.0.5 11972.37 89.21 138.71 5160.51 5222.33 7080.28 8364.62 7084.32 -6719.19 -2244.98 7.36 5973796.43 616792.11 N 70.33715642 W 149.0 5 12004.30 89.76 138.19 5160.80 5222.62 7097.15 8396.55 7100.32 -6743.09 -2223.81 2.37 5973772.88 616813.67 N 70.33709116 W 149.0 39 12036.83 91.06 138.76 5160.56 5222.38 7114.36 8429.08 7116.75 -6767.44 -2202.24 4.36 5973748.87 616835.61 N 70.33702465 W 149.05202138 12068.61 92.19 137.18 5159.66 5221.48 7130.92 8460.85 7132.66 -6791.04 -2180.97 6.11 5973725.62 616857.25 N 70.33696020 W 149.05184878 12100.78 92.19 137.04 5158.43 5220.25 7147.27 8492.99 7148.45 -6814.59 -2159.10 0.43 5973702.42 616879.50 N 70.33689588 W 149.05167124 Last MWD+IFR:AK 12132.70 90.17 135.19 5157.78 5219.60 7163.02 8524.90 7163.75 -6837.59 -2136.97 8.58 5973679.78 616901.98 N 70.33683307 W 149.05149173 TD (Projected lAB) 12190.00 88.12 135.19 5158.63 5220.45 7190.49 8582.19 7190.68 -6878.23 -2096.60 3.58 5973639.78 616942.99 N 70.33672206 W 149.05116408 Survey Type: Definitive Survey NOTES: MWD + IFR : AK - ( MWD + IFR [Alaska] -- In-field referenced MWD in Alaska. Model takes account of increased violence of magnetic field disturbances in Alaska. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leqal Description: Surface: 4346 FSL 4500 FEL S35 T12N R12E UM Tie-In: 4346 FSL 4500 FEL S35 T12N R12E UM BHL: 2747 FSL 1326 FEL S3 T11N R12E UM Northinq (y) rnUSl 5980549.84 5980549.89 5973639.78 Eastinq (X) rnUSl 618929.96 618929.86 616942.99 . SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\S-213A \S-213A Generated 3/7/2005 1 :00 PM Page 7 of 7 SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: polaris Well. . . . . . . . . . . . . . . . . . . . .: S-213A API number..... ..........: 50-029-22993-01 Engineer. . . . . . . . . . . . . . . . .: S. Moy Rig: . . . . . . . . . . . . . . . . . . . . .: Doyon 16 STATE:... ................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... ...... ..: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..... .....: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 35.90 ft KB above permanent.... ...: 0.00 ft OF above permanent.......: 61.82 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 196.54 degrees [(c)2005 IDEAL 108 1C_02] 8-Feb-2005 11:50:23 Spud date... . . . . . . . . . . . . . : Last survey date. ........: Total accepted surveys...: MD of first survey.......: MD of last survey. .......: Page 1 of 10 23-Nov-04 08-Feb-05 245 0.00 ft 12190.00 ft . ----- Geomagnetic data ---------------------- Magnetic model....... ....: BGGM version 2002 Magnetic date. ..... ......: 24-Nov-2004 Magnetic field strength..: 1152.21 HCNT Magnetic dec (+E/W-). ....: 24.83 degrees Magnetic dip.............: 80.84 degrees ----- MWD survey Reference Reference G..............: Reference H.......... ....: Reference Dip..... .......: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip...... ...: Criteria --------- 1002.68 mGal 1152.21 HCNT 80.84 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.83 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.83 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction . 20 (/- ),1 J SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 2 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 297.52 0.00 0.00 -0.02 0.05 -0.10 0.11 296.57 0.00 TIP None 2 155.42 0.08 297.52 155.42 155.42 -0.04 0.10 -0.20 0.22 297.04 0.05 MWD IFR AK 233.49 - - 3 0.19 189.70 78.07 233.49 0.08 -0.00 -0.27 0.27 269.51 0.29 MWD IFR AK 327 . 03 217 .18 93.54 - - 4 0.28 327 . 03 0.45 -0.34 -0.43 0.55 231. 93 0.15 MWD IFR AK - - 5 415.75 0.46 188.45 88.72 415.75 1. 00 -0.86 -0.61 1. 06 215.45 0.29 MWD IFR AK - 6 509.99 0.27 140.23 94.24 509.99 1. 50 -1.41 -0.53 1. 50 200.55 0.37 MWD IFR AK . 602.31 0.35 136.82 92.32 602.30 - 7 1. 76 -1.78 -0.20 1. 79 186.27 0.09 MWD IFR AK - 8 694.94 0.40 110.75 92.63 694.93 1. 93 -2.10 0.30 2.12 171.86 0.19 MWD IFR AK - 9 787.96 0.15 142.58 93.02 787.95 2.02 -2.31 0.68 2.41 163.66 0.31 MWD IFR AK 883.26 - - 10 0.36 98.80 95.30 883.25 2.06 -2.46 1. 05 2.67 156.87 0.29 MWD IFR AK - 11 976.53 0.43 98.44 93.27 976.52 1. 97 -2.55 1. 69 3.06 146.57 0.08 MWD IFR AK - 12 1069.16 0.53 98.28 92.63 1069.14 1. 86 -2.67 2.45 3.62 137.38 0.11 MWD IFR AK - 13 1160.63 0.56 78.60 91. 47 1160.61 1. 59 -2.64 3.31 4.23 128.56 0.21 MWD IFR AK - - 14 1253.35 0.77 70.45 92.72 1253.32 1. 01 -2.34 4.34 4.93 118.33 0.25 MWD IFR AK - 15 1347.39 1. 25 70.29 94.04 1347.35 0.03 -1.78 5.90 6.17 106.81 0.51 MWD IFR AK 16 1439.53 1. 80 76.02 92.14 1439.46 -1.30 -1. 09 8.25 8.33 97.56 0.62 MWD IFR AK - - 17 1534.40 1. 41 74.91 94.87 1534.29 -2.67 -0.43 10.83 10.83 92.28 0.41 MWD IFR AK 1630.00 - - 18 0.74 66.98 95.60 1629.87 -3.68 0.12 12.53 12.53 89.47 0.72 MWD IFR AK - - 19 1723.15 2.46 259.23 93.15 1723.00 -3.14 -0.02 11.12 11.12 90.11 3.42 MWD IFR AK - 20 1814.13 6.28 254.60 90.98 1813.70 0.39 -1.71 4.40 4.72 111. 22 4.21 MWD IFR AK - 21 1863.71 6.40 256.71 49.58 1862.97 3.19 -3.06 -0.90 3.19 196.41 0.53 MWD IFR AK . - - 22 1907.37 6.39 253.07 43.66 1906.36 5.74 -4.33 -5.60 7.08 232.26 0.93 MWD IFR AK - - 23 2000.61 6.09 240.31 93.24 1999.05 12.18 -8.29 -14.86 17.01 240.83 1. 52 MWD I FR AK 24 2095.16 239.01 - 5.63 94.55 2093.11 19.22 -13.16 -23.19 26.66 240.42 0.51 MWD IFR AK 25 2187.42 5.36 237.61 - 92.26 2184.95 25.81 -17 . 80 -30.71 35.49 239.90 0.33 MWD IFR AK 26 2282.02 5.13 235.24 94.60 2279.15 32.44 -22.58 -37.91 44.13 239.22 0.33 MWD IFR AK - - 27 2375.30 7.07 239.64 93.28 2371.90 39.89 -27.86 -46.29 54.03 238.96 2.14 MWD IFR AK 2469.73 12.17 244.54 - - 28 94.43 2464.97 50.80 -35.08 -60.30 69.77 239.81 5.47 MWD IFR AK - 29 2503.22 14.39 244.19 33.49 2497.56 55.96 -38.41 -67.24 77.44 240.26 6.63 MWD IFR AK - 30 2532.82 15.76 243.38 29.60 2526.14 61. 19 -41.81 -74.14 85.12 240.58 4.68 MWD IFR AK - [(c)2005 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 3 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2562.81 17.56 242.48 29.99 2554.87 67.12 -45.73 -81.80 93.71 240.79 6.06 MWD IFR AK - - 32 2591.90 19.43 241.38 29.09 2582.46 73.61 -50.08 -89.94 102.94 240.89 6.54 MWD IFR AK - - 33 2628.07 19.93 240.84 36.17 2616.52 82.28 -55.96 -100.60 115.12 240.91 1. 47 MWD IFR AK - 34 2655.84 20.53 241.04 27.77 2642.57 89.15 -60.62 -109.00 124.72 240.92 2.17 MWD IFR AK - 35 2686.92 21. 45 241.15 31. 08 2671.59 97.08 -66.01 -118.74 135.85 240.93 2.96 MWD IFR AK 36 2718.71 22.14 240.27 31. 79 2701.11 105.54 -71.78 -129.03 147.66 240.91 2.40 MWD IFR AK - - . 37 2749.91 23.21 238.46 31. 20 2729.90 114.37 -77.91 -139.38 159.68 240.80 4.09 MWD IFR AK - 38 2798.38 24.47 236.38 48.47 2774.23 129.18 -88.47 -155.88 179.24 240.42 3.12 MWD IFR AK - 39 2856.54 26.47 236.45 58.16 2826.74 148.38 -102.30 -176.72 204.19 239.93 3.44 MWD Inc only - - 40 2909.66 29.58 236.00 53.12 2873.62 167.59 -116.18 -197.46 229.10 239.53 5.87 MWD Inc only - 41 3006.92 33.61 231.80 97.26 2956.46 208.12 -146.27 -238.53 279.81 238.48 4.72 MWD IFR MS - - 42 3102.80 37.72 227.46 95.88 3034.35 254.98 -182.53 -281. 02 335.10 237.00 5.03 MWD IFR MS - - 43 3199.21 41.06 226.91 96.41 3108.85 307.61 -224.11 -325.89 395.51 235.48 3.48 MWD IFR MS - - 44 3295.21 43.34 232.11 96.00 3179.99 361.64 -265.90 -374.94 459.65 234.66 4.34 MWD IFR MS - - 45 3392.93 45.61 237.12 97.72 3249.73 415.45 -305.47 -430.75 528.07 234.66 4.28 MWD IFR MS 46 3488.29 44.79 237.13 95.36 3316.92 466.84 -342.20 -487.57 595.67 234.94 0.86 MWD I FR MS - 47 3584.58 45.23 235.98 96.29 3385.00 519.00 -379.73 -544.39 663.75 235.10 0.96 MWD IFR MS - 48 3680.92 44.69 235.88 96.34 3453.17 571.61 -417.86 -600.78 731. 81 235.18 0.57 MWD IFR MS - 49 3776.78 45.06 236.81 95.86 3521.10 623.56 -455.34 -657.08 799.44 235.28 0.79 MWD IFR MS - - 50 3873.18 44.60 236.48 96.40 3589.47 675.55 -492.71 -713.85 867.38 235.39 0.53 MWD IFR MS 51 3968.74 44.05 237.25 95.56 3657.83 726.45 -529.21 -769.76 934.13 235.49 0.81 MWD I FR MS . - 52 4064.79 43.64 237.36 96.05 3727.11 776.84 -565.15 -825.75 1000.63 235.61 0.43 MWD IFR MS - 53 4160.95 43.86 238.30 96.16 3796.57 826.81 -600.55 -882.04 1067.08 235.75 0.71 MWD IFR MS - 54 4257.35 43.42 238.37 96.40 3866.33 876.40 -635.48 -938.66 1133.54 235.90 0.46 MWD I FR MS - 55 4348.86 43.94 237.59 91. 51 3932.51 923.78 -668.99 -992.25 1196.70 236.01 0.82 MWD IFR MS 56 4446.91 43.12 237.35 98.05 4003.60 974.80 -705.30 -1049.18 1264.21 236.09 0.85 MWD IFR MS - 57 4545.83 44.42 236.52 98.92 4075.03 1026.92 -742.64 -1106.52 1332.63 236.13 1. 44 MWD IFR MS - 58 4641.52 44.65 236.80 95.69 4143.24 1078.24 -779.52 -1162.59 1399.74 236.16 0.32 MWD IFR MS - 59 4737.67 43.99 236.28 96.15 4212.03 1129.70 -816.56 -1218.63 1466.91 236.18 0.78 MWD IFR MS - 60 4831.97 43.63 236.15 94.30 4280.08 1179.94 -852.86 -1272.89 1532.19 236.18 0.39 MWD IFR MS [(c)2005 IDEAL 108 1C 02] SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 4 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- disp1 Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 4928.03 44.71 235.59 96.06 4348.98 1231.72 -890.42 -1328.29 1599.13 236.16 1. 20 MWD IFR MS - 62 5023.20 44.27 235.98 95.17 4416.87 1283.37 -927.92 -1383.44 1665.82 236.15 0.54 MWD IFR MS - 63 5119.83 43.93 235.90 96.63 4486.27 1335.33 -965.58 -1439.15 1733.06 236.14 0.36 MWD IFR MS - 64 5216.82 44.04 234.58 96.99 4556.05 1387.89 -1003.98 -1494.49 1800.41 236.11 0.95 MWD IFR MS - 65 5313.24 44.17 235.63 96.42 4625.29 1440.36 -1042.37 -1549.53 1867.50 236.07 0.77 MWD IFR MS - 66 5409.71 43.74 235.73 96.47 4694.74 1492.30 -1080.12 -1604.83 1934.46 236.06 0.45 MWD IFR MS . - 67 5505.37 45.59 235.49 95.66 4762.77 1544.50 -1118.10 -1660.32 2001.70 236.04 1. 94 MWD IFR MS - 68 5602.48 48.31 234.89 97.11 4829.06 1599.92 -1158.62 -1718.57 2072.65 236.01 2.84 MWD IFR MS - 69 5697.64 51. 38 233.90 95.16 4890.42 1657.35 -1200.97 -1777.69 2145.34 235.96 3.32 MWD IFR MS - 70 5793.44 54.39 235.09 95.80 4948.22 1717.57 -1245.31 -1839.88 2221.70 235.91 3.29 MWD IFR MS - 71 5889.06 57.95 233.06 95.62 5001. 45 1780.56 -1291. 93 -1904.17 2301.07 235.84 4.12 MWD IFR MS - 72 5985.53 61. 01 230.89 96.47 5050.44 1848.27 -1343.13 -1969.60 2383.97 235.71 3.72 MWD IFR MS - 73 6079.45 65.32 228.53 93.92 5092.83 1918.41 -1397.33 -2033.48 2467.31 235.50 5.11 MWD IFR MS ~ 74 6175.48 70.04 227.10 96.03 5129.29 1994.33 -1456.98 -2099.28 2555.34 235.24 5.10 MWD IFR MS - 75 6270.97 73.80 224.33 95.49 5158.93 2073.57 -1520.36 -2164.22 2644.88 234.91 4.81 MWD IFR MS 76 6367.97 77.84 222.09 97.00 5182.69 2157.59 -1588.90 -2228.58 2737.00 234.51 4.73 MWD IFR MS - 77 6461.21 79.51 218.49 93.24 5201.00 2241. 26 -1658.63 -2287.69 2825.69 234.06 4.19 MWD IFR MS - 78 6555.03 79.70 217.97 93.82 5217.93 2327.01 -1731.11 -2344.79 2914.58 233.56 0.58 MWD IFR MS - 79 6656.75 82.13 217.89 101. 72 5233.99 2420.53 -1810.34 -2406.53 3011. 43 233.05 2.39 MWD IFR MS - 80 6751.71 81. 21 217.48 94.96 5247.75 2508.16 -1884.69 -2463.97 3102.13 232.59 1. 06 MWD IFR MS - 81 6810.09 81.64 217.31 58.38 5256.45 2562.10 -1930.55 -2499.02 3157.87 232.31 0.79 MWD IFR MS . - 82 6945.77 87.98 217.84 135.68 5268.72 2688.16 -2037.59 -2581.38 3288.66 231. 71 4.69 MWD IFR MS - 83 6976.80 89.51 217.96 31. 03 5269.40 2717.05 -2062.07 -2600.44 3318.80 231.59 4.95 MWD IFR MS - - 84 7009.30 90.09 217.29 32.50 5269.51 2747.37 -2087.81 -2620.28 3350.34 231.45 2.73 MWD IFR MS - 85 7040.02 92.73 216.14 30.72 5268.75 2776.19 -2112.42 -2638.64 3380.05 231. 32 9.37 MWD IFR MS - 86 7073.77 95.31 214.11 33.75 5266.39 2808.10 -2139.96 -2658.01 3412.39 231.16 9.72 MWD IFR MS - 87 7105.75 94.69 215.09 31. 98 5263.60 2838.39 -2166.18 -2676.10 3442.94 231.01 3.62 MWD IFR MS - - 88 7136.68 93.93 211.99 30.93 5261.28 2867.88 -2191.88 -2693.13 3472.37 230.86 10.29 MWD IFR MS - 89 7169.47 92.66 211.87 32.79 5259.39 2899.44 -2219.67 -2710.45 3503.35 230.68 3.89 MWD IFR MS - - 90 7201.16 92.56 210.72 31. 69 5257.95 2930.05 -2246.72 -2726.89 3533.22 230.51 3.64 MWD IFR MS [(c)2005 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 5 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 7232.12 93.90 207.09 30.96 5256.20 2960.24 -2273.77 -2741.83 3561. 98 230.33 12.48 MWD IFR MS - 92 7264.98 94.31 204.05 32.86 5253.85 2992.61 -2303.33 -2755.98 3591. 76 230.11 9.31 MWD IFR MS - - 93 7297.58 94.86 200.30 32.60 5251.24 3024.94 -2333.42 -2768.24 3620.50 229.87 11. 59 MWD IFR MS - - 94 7328.71 96.62 196.14 31.13 5248.13 3055.89 -2362.83 -2777.92 3646.89 229.62 14.45 MWD IFR MS - - 95 7361. 45 97.04 191. 74 32.74 5244.23 3088.36 -2394.37 -2785.75 3673.34 229.32 13.41 MWD IFR MS - 96 7397.13 97.76 189.52 35.68 5239.64 3123.55 -2429.15 -2792.28 3701.02 228.98 6.49 MWD IFR MS . - - 97 7424.69 97.69 192.23 27.56 5235.93 3150.72 -2455.96 -2797.43 3722.55 228.72 9.75 MWD IFR MS - - 98 7458.04 97.28 190.53 33.35 5231.59 3183.65 -2488.38 -2803.95 3748.89 228.41 5.20 MWD IFR MS - - 99 7490.69 96.34 189.30 32.65 5227.72 3215.86 -2520.31 -2809.54 3774.32 228.11 4.72 MWD IFR MS - - 100 7520.99 96.27 189.53 30.30 5224.39 3245.74 -2550.02 -2814.46 3797.87 227 . 82 0.79 MWD IFR MS 101 7554.64 95.14 191. 26 33.65 5221.04 3279.03 -2582.96 -2820.50 3824.51 227.52 6.12 MWD IFR MS - - 102 7586.51 93.21 192.59 31. 87 5218.72 3310.71 -2614.05 -2827.07 3850.40 227.24 7.35 MWD IFR MS - - 103 7616.46 93.28 189.18 29.95 5217.03 3340.46 -2643.41 -2832.72 3874.52 226.98 11. 37 MWD IFR MS - 104 7651.28 94.21 189.12 34.82 5214.75 3374.92 -2677.72 -2838.24 3902.02 226.67 2.68 MWD IFR MS - 105 7683.22 94.62 187.30 31.94 5212.29 3406.43 -2709.23 -2842.79 3927.01 226.38 5.82 MWD IFR MS - 106 7712.72 93.97 184.81 29.50 5210.08 3435.35 -2738.48 -2845.89 3949.48 226.10 8.70 MWD IFR MS - 107 7746.50 93.25 183.38 33.78 5207.96 3468.27 -2772 .11 -2848.30 3974.60 225.78 4.73 MWD IFR MS - 108 7779.09 92.90 188.09 32.59 5206.21 3500.23 -2804.48 -2851.55 3999.56 225.48 14.47 MWD I FR MS - 109 7808.86 93.18 185.36 29.77 5204.63 3529.52 -2834.00 -2855.03 4022.78 225.21 9.21 MWD IFR MS - 110 7843.78 93.35 183.78 34.92 5202.64 3563.62 -2868.75 -2857.81 4049.30 224.89 4.54 MWD IFR MS 111 7875.23 93.49 187.64 31.45 5200.76 3594.45 -2899.98 -2860.93 4073.68 224.61 12.26 MWD IFR MS . - 112 7906.37 91. 36 186.76 31. 14 5199.45 3625.15 -2930.85 -2864.83 4098.43 224.35 7.40 MWD IFR MS - 113 7938.57 89.34 185.78 32.20 5199.25 3656.83 -2962.85 -2868.35 4123.82 224.07 6.97 MWD IFR MS - - 114 7969.00 89.82 182.29 30.43 5199.47 3686.53 -2993.20 -2870.49 4147.16 223.80 11. 58 MWD IFR MS - 115 8001. 89 90.64 181.69 32.89 5199.34 3718.37 -3026.07 -2871. 63 4171.74 223.50 3.09 MWD IFR MS - 116 8034.59 91.02 185.42 32.70 5198.87 3750.22 -3058.70 -2873.66 4196.85 223.21 11.46 MWD I FR MS - 117 8065.97 91. 22 181.84 31.38 5198.25 3780.80 -3090.01 -2875.65 4221.07 222.94 11.42 MWD IFR MS - 118 8097.79 90.54 184.08 31. 82 5197.76 3811.72 -3121.78 -2877.29 4245.50 222.67 7.36 MWD IFR MS - 119 8130.33 88.31 185.41 32.54 5198.09 3843.57 -3154.20 -2879.98 4271.21 222.40 7.98 MWD IFR MS - 120 8161. 64 87.35 185.47 31. 31 5199.28 3874.27 -3185.35 -2882.95 4296.26 222.15 3.07 MWD IFR MS [(c)2005 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 6 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100£) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 8193.93 88.79 183.80 32.29 5200.36 3905.85 -3217.51 -2885.55 4321. 90 221.89 6.83 MWD IFR MS - 122 8226.32 88.65 184.52 32.39 5201.09 3937.48 -3249.81 -2887.90 4347.56 221.63 2.26 MWD IFR MS - 123 8256.93 88.38 184.88 30.61 5201.88 3967.42 -3280.30 -2890.41 4372.06 221.38 1. 47 MWD IFR MS - 124 8289.45 88.65 185.12 32.52 5202.72 3999.28 -3312.69 -2893.24 4398.27 221.13 1.11 MWD IFR MS - 125 8321.57 89.13 186.90 32.12 5203.35 4030.85 -3344.63 -2896.60 4424.57 220.89 5.74 MWD IFR MS 126 8353.11 88.55 187.55 31. 54 5203.98 4061.97 -3375.91 -2900.57 4450.85 220.67 2.76 MWD IFR MS - . 127 8385.72 89.61 187.18 32.61 5204.51 4094.15 -3408.25 -2904.75 4478.14 220.44 3.44 MWD IFR MS - 128 8417.71 90.47 188.33 31. 99 5204.49 4125.77 -3439.94 -2909.07 4505.09 220.22 4.49 MWD IFR MS - 129 8449.35 90.54 186.84 31.64 5204.21 4157.02 -3471.30 -2913.24 4531.77 220.00 4.71 MWD IFR MS - 130 8481. 45 91.46 183.78 32.10 5203.65 4188.50 -3503.26 -2916.21 4558.19 219.78 9.95 MWD IFR MS 131 8513.48 91.87 187.07 32.03 5202.71 4219.91 -3535.13 -2919.24 4584.66 219.55 10.35 MWD IFR MS - 132 8545.26 91.12 185.20 31.78 5201.89 4251.15 -3566.71 -2922.63 4611.21 219.33 6.34 MWD IFR MS - 133 8577.81 89.95 186.18 32.55 5201.58 4283.12 -3599.10 -2925.86 4638.34 219.11 4.69 MWD IFR MS - 134 8610.07 90.06 183.67 32.26 5201.58 4314.72 -3631.24 -2928.63 4665.06 218.89 7.79 MWD IFR MS - 135 8641.85 90.78 184.52 31.78 5201. 35 4345.75 -3662.93 -2930.90 4691.19 218.67 3.51 MWD IFR MS 136 8673.97 90.91 186.55 32.12 5200.87 4377.27 -3694.90 -2934.00 4718.12 218.45 6.33 MWD IFR MS - 137 8706.18 90.98 184.16 32.21 5200.34 4408.86 -3726.96 -2937.00 4745.13 218.24 7.42 MWD IFR MS - 138 8738.14 91. 98 184.51 31. 96 5199.52 4440.09 -3758.82 -2939.42 4771.68 218.03 3.31 MWD IFR MS - 139 8771. 07 93.66 187.04 32.93 5197.90 4472.40 -3791.54 -2942.73 4799.52 217 . 82 9.21 MWD IFR MS - 140 8803.65 93.01 187.94 32.58 5196.00 4504.52 -3823.79 -2946.97 4827.62 217 .62 3.40 MWD IFR MS 141 8834.93 92.66 184.75 31. 28 5194.45 4535.26 -3854.83 -2950.42 4854.35 217.43 10.25 MWD IFR MS . - 142 8865.08 92.36 186.14 30.15 5193.13 4564.82 -3884.82 -2953.28 4879.92 217.24 4.71 MWD IFR MS - - 143 8899.41 90.78 184.81 34.33 5192.19 4598.50 -3918.97 -2956.55 4909.13 217.03 6.01 MWD IFR MS - 144 8931.45 90.64 186.83 32.04 5191. 79 4629.97 -3950.85 -2959.80 4936.56 216.84 6.32 MWD IFR MS - - 145 8962.45 90.81 188.48 31. 00 5191. 40 4660.60 -3981.57 -2963.93 4963.64 216.66 5.35 MWD IFR MS 146 8996.97 89.85 187.15 34.52 5191.20 4694.72 -4015.76 -2968.62 4993.90 216.47 4.75 MWD I FR MS - 147 9026.75 89.47 185.30 29.78 5191.38 4724.01 -4045.37 -2971.85 5019.65 216.30 6.34 MWD I FR MS - 148 9058.08 89.54 183.62 31.33 5191.65 4754.65 -4076.60 -2974.29 5046.29 216.11 5.37 MWD IFR MS - 149 9091.47 89.24 186.19 33.39 5192.01 4787.35 -4109.86 -2977.14 5074.87 215.92 7.75 MWD IFR MS - 150 9123.55 89.54 185.42 32.08 5192.35 4818.86 -4141. 77 -2980.39 5102.65 215.74 2.58 MWD IFR MS [(c)2005 IDEAL ID8_1C_02J SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 7 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 9153.20 89.78 185.41 29.65 5192.52 4847.95 -4171. 29 -2983.18 5128.26 215.57 0.81 MWD IFR MS - 152 9186.04 89.82 185.80 32.84 5192.64 4880.20 -4203.98 -2986.39 5156.74 215.39 1.19 MWD IFR MS - 153 9220.52 89.61 186.52 34.48 5192.81 4914.11 -4238.25 -2990.09 5186.85 215.20 2.18 MWD IFR MS - 154 9249.91 88.93 186.22 29.39 5193.18 4943.04 -4267.46 -2993.35 5212.62 215.05 2.53 MWD IFR MS - 155 9282.10 88.34 183.92 32.19 5193.95 4974.57 -4299.51 -2996.20 5240.52 214.87 7.37 MWD IFR MS 156 9314.67 87.38 184.98 32.57 5195.17 5006.40 -4331.96 -2998.72 5268.61 214.69 4.39 MWD IFR MS . - 157 9345.63 87.31 181. 67 30.96 5196.60 5036.50 -4362.83 -3000.51 5295.03 214.52 10.68 MWD IFR MS - 158 9379.10 87.32 183.63 33.47 5198.17 5068.96 -4396.23 -3002.06 5323.46 214.33 5.85 MWD IFR MS - 159 9410.58 87.45 182.97 31.48 5199.61 5099.57 -4427.62 -3003.87 5350.43 214.15 2.13 MWD IFR MS - 160 9442.20 88.27 184.66 31.62 5200.79 5130.39 -4459.15 -3005.97 5377.72 213.98 5.94 MWD IFR MS 161 9475.15 88.96 183.10 32.95 5201.58 5162.53 -4492.01 -3008.20 5406.24 213.81 5.18 MWD IFR MS - - 162 9507.89 88.00 184.30 32.74 5202.45 5194.44 -4524.67 -3010.31 5434.58 213.64 4.69 MWD IFR MS - - 163 9538.29 88.86 186.01 30.40 5203.29 5224.23 -4554.94 -3013.04 5461.31 213.48 6.29 MWD IFR MS - 164 9571.34 89.54 185.82 33.05 5203.75 5256.71 -4587.81 -3016.45 5490.62 213.32 2.14 MWD IFR MS - 165 9603.61 87.97 184.52 32.27 5204.45 5288.33 -4619.94 -3019.36 5519.09 213 .17 6.32 MWD IFR MS - 166 9633.58 88.52 181. 48 29.97 5205.37 5317.45 -4649.85 -3020.92 5545.00 213.01 10.30 MWD IFR MS - - 167 9667.64 88.24 185.76 34.06 5206.33 5350.63 -4683.82 -3023.07 5574.69 212.84 12.59 MWD IFR MS - - 168 9698.72 89.10 185.45 31. 08 5207.05 5381.14 -4714.74 -3026.11 5602.33 212.69 2.94 MWD IFR MS - - 169 9729.92 89.85 183.26 31. 20 5207.34 5411.63 -4745.85 -3028.48 5629.81 212.54 7.42 MWD IFR MS - 170 9765.67 90.33 182.31 35.75 5207.28 5446.35 -4781.56 -3030.21 5660.87 212.36 2.98 MWD IFR MS 171 9796.46 89.82 184.02 30.79 5207.24 5476.31 -4812.30 -3031.91 5687.77 212.21 5.80 MWD IFR MS . - - 172 9828.53 88.86 182.80 32.07 5207.61 5507.54 -4844.31 -3033.82 5715.89 212.06 4.84 MWD IFR MS - - 173 9860.43 87.32 181.63 31. 90 5208.67 5538.43 -4876.16 -3035.05 5743.56 211. 90 6.06 MWD IFR MS - - 174 9892.46 88.34 178.61 32.03 5209.89 5569.12 -4908.17 -3035.12 5770.79 211.73 9.95 MWD IFR MS - 175 9925.34 88.69 180.05 32.88 5210.74 5600.52 -4941.03 -3034.73 5798.57 211.56 4.51 MWD IFR MS - 176 9955.86 89.10 177.17 30.52 5211.33 5629.55 -4971.54 -3033.99 5824.20 211.39 9.53 MWD IFR MS - - 177 9988.03 89.20 181.28 32.17 5211.80 5660.25 -5003.69 -3033.56 5851.45 211.23 12.78 MWD IFR MS - - 178 10020.48 88.48 179.27 32.45 5212.46 5691. 40 -5036.13 -3033.72 5879.29 211.06 6.58 MWD IFR MS - 179 10052.71 89.37 178.65 32.23 5213.07 5722.11 -5068.35 -3033.13 5906.61 210.90 3.37 MWD IFR MS - 180 10084.38 91. 46 178.22 31. 67 5212.84 5752.21 -5100.01 -3032.27 5933.36 210.73 6.74 MWD IFR MS [(c)2005 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 8 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Disp1 Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 181 10116.55 92.08 178.39 32.17 5211.84 5782.75 -5132.15 -3031.31 5960.52 210.57 2.00 MWD IFR MS - 182 10148.54 92.15 180.40 31.99 5210.66 5813.30 -5164.11 -3030.98 5987.89 210.41 6.28 MWD IFR MS - 183 10180.37 92.08 180.54 31. 83 5209.49 5843.86 -5195.92 -3031.24 6015.48 210.26 0.49 MWD IFR MS - 184 10211.67 92.70 177.95 31. 30 5208.18 5873.72 -5227.19 -3030.83 6042.30 210.11 8.50 MWD IFR MS - 185 10243.39 91.74 182.62 31.72 5206.95 5904.14 -5258.87 -3030.98 6069.81 209.96 15.02 MWD IFR MS - 186 10275.20 90.61 17 9.64 31.81 5206.30 5934.80 -5290.67 -3031.61 6097.69 209.81 10.02 MWD IFR MS . - 187 10307.76 88.28 181.20 32.56 5206.62 5966.07 -5323.22 -3031.85 6126.07 209.66 8.61 MWD IFR MS - 188 10338.68 87.55 178.97 30.92 5207.74 5995.70 -5354.12 -3031.90 6152.96 209.52 7.58 MWD IFR MS - 189 10371.26 88.34 177.65 32.58 5208.91 6026.63 -5386.66 -3030.93 6180.83 209.37 4.72 MWD IFR MS - 190 10401.85 88.21 178.90 30.59 5209.83 6055.66 -5417.22 -3030.01 6207.04 209.22 4.11 MWD IFR MS 191 10434.75 87.11 176.76 32.90 5211.17 6086.80 -5450.07 -3028.77 6235.12 209.06 7.31 MWD IFR MS - - 192 10466.54 87.04 175.75 31.79 5212.79 6116.58 -5481.75 -3026.70 6261.83 208.90 3.18 MWD IFR MS - - 193 10499.01 87.35 173.12 32.47 5214.38 6146.62 -5514.03 -3023.55 6288.59 208.74 8.15 MWD IFR MS - 194 10531.42 87.38 169.78 32.41 5215.87 6175.94 -5546.04 -3018.74 6314.37 208.56 10.29 MWD IFR MS - - 195 10563.56 87.35 170.46 32.14 5217.35 6204.69 -5577.67 -3013.23 6339.55 208.38 2.12 MWD IFR MS 196 10596.09 87.62 167.52 32.53 5218.78 6233.50 -5609.56 -3007.02 6364.70 208.19 9.07 MWD IFR MS - 197 10627.42 86.94 168.19 31. 33 5220.27 6260.95 -5640.16 -3000.44 6388.58 208.01 3.05 MWD IFR MS - 198 10659.90 87.04 166.77 32.48 5221.97 6289.30 -5671. 82 -2993.41 6413.27 207.82 4.38 MWD IFR MS - 199 10692.13 90.95 166.28 32.23 5222.54 6317.20 -5703.15 -2985.90 6437.51 207.63 12.23 MWD IFR MS - 200 10724.10 92.98 168.36 31. 97 5221.44 6345.08 -5734.32 -2978.89 6461.90 207.45 9.09 MWD IFR MS 201 10755.88 92.85 166.96 31.78 5219.83 6372.88 -5765.33 -2972.11 6486.32 207.27 4.42 MWD IFR MS . - - 202 10788.42 92.40 165.81 32.54 5218.33 6400.98 -5796.92 -2964.45 6510.93 207.08 3.79 MWD IFR MS - 203 10820.36 92.71 159.92 31. 94 5216.91 6427.52 -5827.40 -2955.06 6533.83 206.89 18.45 MWD IFR MS - 204 10852.35 92.61 159.56 31. 99 5215.43 6453.11 -5857.37 -2943.99 6555.60 206.68 1.17 MWD IFR MS - 205 10884.67 91. 85 157.12 32.32 5214.17 6478.49 -5887.39 -2932.07 6577.11 206.47 7.90 MWD IFR MS 206 10916.59 91. 92 155.73 31. 92 5213 .12 6502.89 -5916.63 -2919.31 6597.64 206.26 4.36 MWD IFR MS - 207 10948.69 91. 20 156.06 32.10 5212.24 6527.23 -5945.92 -2906.21 6618.15 206.05 2.47 MWD IFR MS - - 208 10979.35 92.20 156.76 30.66 5211.33 6550.66 -5974.00 -2893.94 6638.04 205.85 3.98 MWD IFR MS - 209 11012.52 90.75 156.32 33.17 5210.48 6576.06 -6004.42 -2880.74 6659.71 205.63 4.57 MWD IFR MS - 210 11044.83 89.90 146.04 32.31 5210.30 6598.74 -6032.69 -2865.19 6678.52 205.41 31.92 MWD IFR MS [(c)2005 IDEAL ID8 1C 02] SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 9 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 211 11075.11 90.00 144.27 30.28 5210.32 6617 . 63 -6057.54 -2847.89 6693.60 205.18 5.85 MWD IFR AK - 212 11108.58 89.35 140.38 33.47 5210.51 6637.20 -6084.02 -2827.44 6708.93 204.93 11.78 MWD IFR AK - 213 11140.86 89.25 142.93 32.28 5210.91 6655.77 -6109.33 -2807.41 6723.51 204.68 7.90 MWD IFR AK - - 214 11171.12 89.31 141. 62 30.26 5211.29 6673.44 -6133.27 -2788.90 6737.58 204.45 4.33 MWD IFR AK - 215 11204.88 89.49 143.49 33.76 5211. 64 6693.28 -6160.07 -2768.38 6753.54 204.20 5.56 MWD IFR AK 216 11236.60 89.49 141.05 31. 72 5211.92 6711.81 -6185.15 -2748.97 6768.52 203.96 7.69 MWD IFR AK . - - 217 11267.19 89.97 133.95 30.59 5212.07 6727.53 -6207.69 -2728.31 6780.79 203.73 23.26 MWD IFR AK - 218 11300.64 89.45 131.96 33.45 5212.24 6742.41 -6230.48 -2703.84 6791.88 203.46 6.15 MWD IFR AK - 219 11332.38 89.14 129.93 31.74 5212.63 6755.52 -6251.28 -2679.86 6801.48 203.20 6.47 MWD IFR AK - - 220 11363.18 88.90 130.17 30.80 5213.15 6767.81 -6271.10 -2656.29 6810.47 202.96 1.10 MWD IFR AK 221 11396.54 89.04 133.37 33.36 5213.75 6782.03 -6293.31 -2631. 42 6821.30 202.69 9.60 MWD IFR AK - 222 11428.43 89.07 133.78 31.89 5214.28 6796.52 -6315.29 -2608.32 6832.73 202.44 1. 29 MWD IFR AK - - 223 11458.92 88.90 132. 68 30.49 5214.82 6810.21 -6336.17 -2586.10 6843.61 202.20 3.65 MWD IFR AK - 224 11492.51 89.21 133.64 33.59 5215.37 6825.26 -6359.14 -2561.61 6855.69 201.94 3.00 MWD IFR AK - 225 11524.40 89.76 135.86 31.89 5215.66 6840.33 -6381. 59 -2538.96 6868.12 201.70 7.17 MWD IFR AK 226 11554.63 88.63 136.77 30.23 5216.09 6855.34 -6403.45 -2518.08 6880.76 201.47 4.80 MWD IFR AK - 227 11587.04 88.42 140.44 32.41 5216.92 6872.54 -6427.75 -2496.66 6895.60 201.23 11. 34 MWD IFR AK - 228 11619.52 87.84 136.77 32.48 5217.98 6889.77 -6452.10 -2475.20 6910.59 200.99 11.43 MWD IFR AK - 229 11649.97 87.77 136.73 30.45 5219.15 6905.08 -6474.26 -2454.35 6923.87 200.76 0.26 MWD IFR AK - 230 11684.36 87.50 142.83 34.39 5220.57 6923.91 -6500.49 -2432.18 6940.59 200.51 17.74 MWD IFR AK 231 11716.33 88.87 142.63 31. 97 5221.58 6942.77 -6525.91 -2412.83 6957.68 200.29 4.33 MWD IFR AK . - - 232 11747.93 90.51 138.81 31. 60 5221. 75 6960.52 -6550.37 -2392.82 6973.73 200.07 13.16 MWD IFR AK - - 233 11778.98 90.24 139.03 31. 05 5221.55 6977.15 -6573.77 -2372.42 6988.77 199.84 1.12 MWD IFR AK - 234 11811.12 89.59 139.11 32.14 5221.60 6994.43 -6598.05 -2351.37 7004.52 199.61 2.04 MWD IFR AK - - 235 11843.68 89.79 137.99 32.56 5221. 77 7011.69 -6622.46 -2329.81 7020.33 199.38 3.49 MWD IFR AK 236 11875.78 89.79 138.42 32.10 5221.89 7028.54 -6646.39 -2308.42 7035.86 199.15 1. 34 MWD IFR AK - - 237 11907.58 90.51 137.15 31. 80 5221. 81 7045.04 -6669.94 -2287.05 7051.15 198.93 4.59 MWD IFR AK - 238 11940.29 89.21 141.07 32.71 5221.89 7062.64 -6694.66 -2265.65 7067.65 198.70 12.63 MWD IFR AK - - 239 11972.37 89.21 138.71 32.08 5222.33 7080.27 -6719.19 -2244.98 7084.31 198.48 7.36 MWD IFR AK - 240 12004.30 89.76 138.19 31. 93 5222.62 7097.15 -6743.09 -2223.80 7100.32 198.25 2.37 MWD IFR AK - [(c)2005 IDEAL ID8 1C 02] . ' SCHLUMBERGER Survey Report 8-Feb-2005 11:50:23 Page 10 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 241 12036.83 91. 06 138.76 32.53 5222.38 7114.36 -6767.44 -2202.24 7116.75 198.03 4.36 MWD IFR AK - 242 12068.61 92.19 137.18 31.78 5221.48 7130.92 -6791.04 -2180.97 7132.66 197.80 6.11 MWD IFR AK - - 243 12100.78 92.19 137.04 32.17 5220.25 7147.27 -6814.59 -2159.09 7148.45 197.58 0.43 MWD IFR AK - - 244 12132.70 90.17 135.19 31. 92 5219.59 7163.02 -6837.59 -2136.97 7163.75 197.36 8.58 MWD IFR AK 245 12190.00 88.12 135.19 57.30 5220.45 7190.49 -6878.23 -2096.60 7190.68 196.95 3.58 Projected to TD IAB Inc~ination . [ (c) 2005 IDEAL 108 1C 02] . . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No S-213A Date Dispatched: 23-Feb-05 Installation/Rig Doyon 16 Dispatched By: 0 Data No Of Prints No of Floppies Surveys 2 Received By: trl-~ œ~? Please sign and return to: Drilling & Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1@slb.com Fax: 907-561-8417 LWD Log DeliveryVl.l, 10-02-03 Schlumberger Private :;(0 '-{-;} /3 II ~~fÆ~E (ill F fÆ~fÆ~~~fÆ ~ ~"#ASIiA OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay S-213A BP Exploration (Alaska) Inc. Permit No: 204-213 Surface Location: 4347' NSL, 4501' WEL, SEC. 35, TI2N, R12E, UM Bottornhole Location: 2757' NSL, 1269' WEL, SEC. 03, T12N, RI2E, UM (OBd) Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to . ness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). y.J4A- ¡ o/U-/z.ðC+ J ALASKA O"-ND ~j(';~g~S~~;:i;ON COM!SIONR PERMIT TO DRILL . 20 MC 25.005 ocr 2 ¿0[4 1b. Current Well Class 0 Exploratory III~~~. Qilllll Multiple ZOI1~ o Stratigraphic Test 0 Service O'O'è'v't!}ð'pttìérífGas EJSingléZ$I!';';:" 5. Bond: a Blanket 0 Single Well 11. Well Nam',fahdiNOmber: Bond No. 2S100302630-277 PBU $-213A / 6. Proposed Depth: 12. Field / Pool(s): MD 12149' TVD 5217' Prudhoe Bay Field I Polaris Pool 7. Property Designation: ADL 028253 o Drill II Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4347' NSL, 4501' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 2321' NSL, 1796' WEL, SEC. 34, T12N, R12E, UM (OBd) Total Depth: '-r/JrOßPÙ 2757' NSL, 1269' WEL, SEC. 03, ~R12E, UM (OBd) 4b. Location of Well (State Base Plane Coordinates): Surface: X-618930 y-5980550 Zone-ASP4 16. Deviated Wells: Kickoff Depth: 2870' feet Maximum Hole Angle: 93 degrees 8. Land Use Permit: 13. Approximate Spud Date: 11/01/04 / 14. Distance to Nearest Property: 9900' 9. Acres in Property: 2560 18;·' Casing Program: I Size Casing 7-5/8" 4-1/2" Hole 8-314" 6-3/4" Weight 29.7# 12.6# specifications Grade Coupling L-80 STL-FJ L-80 IBT Length 6565' 5749' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 61.90' feet 500' away from S-01 at Top OA 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 2312 Surface: 1807'/ ~etting DePtt!i')i Q\.Iari~ of c:ertlèrit Top..', Bottom (c.t.orsacks) MD TVD MD TVD (including staç¡e data) 26' 26' 6591' .5227' 202 sx Class 'G' 6400' 5198' 12149'Y 5217' Uncemented Slotted Liner 19. PRESENT WELl. CONDITION SUMMARY (To be completed forRe~I'ÍUANP.Re-el'\try Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 6520 5608 None 6423 5515 Cå$in9 Lèngth Size CernentVolurne Structural Conductor Surface Intermediate Production Liner Junk (measured): None 110' 2831' 20" 9-5/8" 260 sx Arctic Set (Approx.) 440 sx Arcticset Lite 3, 215 sx CI 'G' 110' 2859' 110' 2829' 6481' 7" 268 sx Class 'G' 6507' 5595' 20. Attachments a Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 5016' - 5268' a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements Perforation Depth MD (ft): 5892' - 6165' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. :~:::,2~n: ¡¿c ::. Sen,,' =:n9;nee, Date fO ~¿-"i s:O-;;~=:~750 Permit To Drill I API Number: Permit Number: .2 <:) y-- 2-1...s 50- 029-22993-01-00 Date: Conditions of Approval: Samples Required [] Yes ~No Mud Log Hydrogen Sulfide Measures Yes .)(No Directional Survey Required Other: '\ë sf- 15 (I P 1-0 ''5 S" tJO f ç (' . Date: Contact Michael Triolo, 564-5774 See cover letter for other requirements [] Yes ,þ(No )sYes [J No -- APPROVED BY THE COMMISSION Date i1~t;caœ · Greater pruee Bay S-213A ML Permit I Type of Well (producer or injector): I Schrader OBd, OBc, OBb, OBa and OA Multilateral Producer I / Surface Location: S-213a OBd Target Start: S-213a OBd Target End: S-213a L 1 OBb Target Start: S-213a L1 OBb Target End: S-213a L2 OBc Target Start: S-213a L2 OBc Target End: S-213a L3 OBa Target Start: S-213a L3 OBa Target End: S-213a L4 OA Target Start: S-213a L4 OA Target End: I AFE Number: I PLD5M1074 4,346' FSL, 4,500' FEL, Sec. 35, T12N, R11 E X = 618,929.96 Y = 5,980,549.84 2,321' FSL, 1,796' FEL, Sec. 34, T12N, R12E X = 616,389.90 Y = 5,978,485.05 Z = 5,180' TVDss 2,757' FSL, 1,269' FEL, Sec. 3, T11N, R12E X = 61 Y = Z = 5,155' TVDss 2,545' FSL, 1,607' FEL, Sec. 34, T12N, R12E X = 616,574.94 Y = 5,978,712.43 Z = 5,120' TVDss 2,757' FSL, 1,269' FEL, Sec. 3, T11 N, R12E X = 616,999.90 Y = 5,973,650.05 Z = 5,060' TVDss 2,172' FSL, 1,873' FEL, Sec. 34, T12N, R12E X = 616,314.90 Y = 5,978,335.05 Z = 5,105' TVDss 2,757' FSL, 1,269' FEL, Sec. 3, T11 N, R12E X = 616,999.90 Y = 5,973,650.05 Z = 5,110' TVDss 'FSL, 1,796' FEL, Sec. 34, T12N, R12E X = 616,389.90 Y = 5,978,485.05 Z = 5,040' TVDss 2,757' FSL, 1,269' FEL, Sec. 3, T11 N, R12E X = 616,999.90 Y = 5,973,650.05 Z = TVDss 2,321' FSL, 1,796' FEL, Sec. 34, T12N, R12E X = 616,389.90 Y = 5,978,485.05 Z = 5,000' TVDss 2,757' FSL, 1,269' FEL, Sec. 3, T11 N, R 12E /' X = 616,999.90 Y = 5,973,650.05 Z = 4,990' TVDss KBE = 61.90' I Rig: I Doyon 16 /' I Estimated Start Date: I Nov. 1Sf 2004 I Operating days to complete: I 50.68 OBd MD 12,149' Well TVDrkb: TD 5,217' Max Inc. ~: KOP 2,870' OBb MD 12,150' Well TVDrkb: TD 5,122' Max Inc. KOP 6,337' OBc MD 12,144' Well TVDrkb: TD 5,172' Max Inc. '"92° KOP 6,634' OBa MD 12,139' Well TVDrkb: TD 5,082' Max Inc. 93° KOP 6,070' OAMD 12,128' Well TVDrkb: TD 5,052' Max Inc. 93° KOP 5,943' Current Well Information Distance to Nearest Property: Distance to Nearest Well in Pool: Original Well API #: Sidetrack API #'s S-213a API OBd #: S-213a L 1 API OBb #: S-213a L2 API OBc #: S-213a L3 API OBa #: S-213a L4 API OA #. Well Type: Current Status: H2S: -9,900' to PBU Unit Boundary at Top OA(this is the closest point in the producing well section to any unit boundary) -500' to S-01 (Ivishak well) at Top OA 50-029-22993-00 50-029-22993-01 50-029-22993-60 50-029-22993-61 50-029-22993-62 50-029-22993-63 Schrader O-sand Penta-lateral Producer / / Planned pre-rig decompletion: Tubing cut at ±5,250' MD / o ppm from produced fluids (approximated to be around 10 ppm due to contaminated gas lift gas) Draft Permit 10/21/04 · Greater pru. Bay S-213A ML Permit BHT: 84 of @ 4,400' TVDss (Estimated) BHP: Static taken on S-213 on 9-18-04 showed a~J"pg EMW. MDT's taken on S-116 on 12/03 agreed wit~~ent static, but also showed higher pressures at the mid/toe of the planned S-213A trajectory OA OBa OBb OBc OBd 2,141(8.15) 5,052 2,338 (8.9) 5,052 Based on Static and MDT pressures 2,160 (8.15) 5,097 2,352 (8.9) 5,082 Based on Static and MDT pressures 2,175 (8.15) 5,132 2,370 (8.9) 5,122 Based on Static and MDT pressures 2,194 (8.15) 5,177 2,394 (8.9) 5,172 Based on Static and MDT pressures 2,215 (8.15) 5,227 2,414 (8.9) 5,217 Based on Static and MDT pressures Cement: TD / PBTD: Is this well frac'd? Mechanical Condition S-213 Wellhead: Base Flange height: Nabor 9ES: Doyon 16: Tubing: Casing Casing Head: Casing Hanger: Tubing Spool: Tubing Head Adapter: Tbg. Hanger: Tree: Open Perfs: Tubing / Casing Fluids: Materials Needed Top of cement on 9-%" casing is at surface. Top of cement on 7" casing is at 3,000' MD based on bond log run on 1/9/01 5,314' MD TOF inside 3-12" tubing. Yes /~ FMC 11" Gen 5 with 7" mandrel hanger Above MSL = 35.90' KB / MSL = 64.40' KB / MSL = 61.90' 3-W', 9.3#, L-80, NSCT with tubing cut @ -5,260' MD. -Cut correlated to GLM @ 5,227 Surface: 9-%",40#, L-80, BTC to 2,859' MD Production: 7", 26#, L-80, BTC from surface to 6,507' MD FMC 11", 5M 7" FMC Mandrel Hanger and packott with 8.000-4 ACME-2G-LH external R&R thread top FMC 11" X 11" 5M FMC 11" X 4-1/16", 5M FMC 11" x 4- W' with 4- W' NSCT pup joint 7.115 aD EN, CIW BPVT Cameron 5M,4-1/16" Currently from 5,892- MD to 6,165' MD (planned to be abandoned with drilling rig) SW with diesel cap down to -2,000' TVD 6,600' 1 each 40 each 2 lots 3 each 7-%" 29.7# L-80 STL-FJ Casing (Burst: 6,890; Collapse: 4,790) 7-%" STL-FJ Float Shoe and Float Collar 7-%" x 8- 12" In-line Centralizers 7-%" casing pups 5', 10',20' (Verify with Unique on stock) 7-%" RA Tag 5 x Production Liners: 29,210' 730 each 4 each 5 each 1 each 1 each 3 assemblies 412",12.6#, L-80, IBT-Mod Slotted Liner 4 W' x 5 3;4" x 8" Straight Blade Centralizers 7-%" x 4-W' Baker ZXP Liner Top Packer 4-W' Halliburton Float Shoes 6" x 3" x 10' Aluminum KO billet 6.4" x 15' EWS Swell Packer Baker Level 3 Hookwall Hangers with LEM 2 Draft Permit 10/21/04 ~ . Greater prue Bay S-213A ML Permit 5,900' 1 each 3 each 1 each 4 each 1 each 5,900' 1 each 4-%",12.6 I b/tt , L-80, BTC-M tubing Baker PRM Production Packer 7-%" X 4-W' Halliburton X-Nipple (3.813" ID) 4-%" Baker CMD Sliding Sleeve Cameo 4-%" X 1" KBG-2 Gas Lift Mandrels Phoenix pressure gauge I-wire for the Phoenix gauge 4-%" WLEG (Unique Machine) Surface and Anti-Collision Issues Surface Shut-in Wells: S-112i and S-120 will need to be shut-in for the rig move on and off S-213A. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Afproach Well List: Mud Program 8-3,4" Intermediate Hole Mud Properties: I Freshwater Mud (LSND) PH: 9.0 - 9.5 Interval!&,sit (ppg) Funnel vis I yp I Tauo I PV I API Filtrate I MBT 9.0 9.3 45 - 60 22 - 30 3 - 6 12 - 18 4 - 6 < 20 . _ Maintain proper fluid rheology & lubricant concentration to achieve the directional Interval Specific requirements Objectives: Optimize mud rheology to maximize ROP while following ECD guidelines Reduce shaker blindin while drillin the UGNU BDF 263 . 6-3,4" Production Hole Mud Properties: LVT-200 MOBM (Versa-Pro) Interval! Density (ppg) Stability I yp I Oil: H20 Ratio I PV I API Filtrate I MBT 9.2 650 - 900 16 - 19 80 : 20 < 20 < 5 < 6 Minimize solids/liquid invasion by maintaining optimum PSD of bridging agents. Maintain minimal ECD's by reducing drill solids accumulation through utilization of the rigs solids control system and effective dilution. Interval Specific Objectives: Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. / BOPE and drilling fluid system schematics are on file with the AOGCC. Production Section- · Maximum anticipated BHP: · Maximum surface pressure: 2,312 psi @ 5,052' TVDss (8.8 ppg EMW). Based on S-116 MDT's 1,807 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Test Frequency: · Planned completion fluid: 3,500 psi (7-%" casing will be tested to 3,500 psi) / 7 day test cycle (Pre drilling phase) !14 day test cycle (Drilling phase) Estimated 9.3 ppg Brine / 6.8 ppg Diesel 5,000 psi Working Pressure (entire stack and valves 3,500/250 psi Rams & Valves 2,500/250 psi Annular / 3 Draft Permit 10/21/04 . Greater pru. Bay S-213A ML Permit Disposal . NO ANNULAR INJECTION ON THIS WELL. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class 1/ wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. Formation Markers SV6 1,561 N/A 718 8.8 Above KOP Base Permafrost 1,901 N/A 874 8.8 Above KOP SV5 2,137 N/A 983 8.8 Above KOP SV4 2,315 N/A 1,065 8.8 Above KOP SV3 2,681 N/A 1,233 8.8 No SV2 2,826 2,926 1,270 8.6 No C¡. 7.- SVl 3,153 3,340 1,427 8.7 Poss. Free Gas btw 3,150 & 3,190' UG4 3,484 3,802 1,585 8.7 No UG4A 3,510 3,839 1,598 8.8 Heavy Oil throughout UG3 3,855 4,320 1,763 8.8 Thin coals UGl 4,410 5,094 2,028 8.8 Heavy Oil throughout Ma 4,654 5,435 2,145 8.9 Yes Mbl 4,705 5,507 2,169 8.9 Yes Mb2 4,750 5,570 2,191 8.9 Oil & Water owe -4766'SS Me 4,825 5,683 2,227 8.9 Yes Na 4,890 5,790 2,258 8.9 Yes Nb 4,905 5,816 2,265 8.9 Yes Ne 4,942 5,884 2,283 8.9 Yes OA 4,990 5,979 2,306 8.9 Yes OBa 5,035 6,080 2,327 8.9 Yes OBb 5,070 6,170 2,344 8.9 Yes OBe 5,115 6,312 2,365 8.9 Yes OBd 5,165 6,591 2,389 8.9 Yes T.D. 5,155 12,149 Yes CasinglTubing Program 8-%" 7-%" 29.7# L-80 STL-FJ 6,565' 26' / 26' 6,591' /5,227' 6-%" OBd 4-%" slotted 12.6# L-80 IBT 5,749' 6,400' / 5,198' 12,149' / 5,217' 6-%" OBb 4-W'slotted 12.6# L-80 IBT 5,516' 6,634' / 5,182' 12,150' /5,122' 6-%" OBc 4-%" slotted 12.6# L-80 IBT 5,832' 6,312' /5,177' 12,144' / 5,172' 6-%" OBa . 4- %" slotted 12.6# L-80 IBT 6,094' 6,045' / 5,082' 12,139' /5,082' 6-%" OA 4-%,'slotted 12.6# L-80 IBT 6,210' 5,918' / 5,022' 12,128' / 5,052' Tubing 4-Y2" 12.6# L-80 IBT-M 5,844' 26' / 26' 5,870' /5,000' Cement Calculations Casing Size 19-% -in 40-lb/ft L-80 BTC surface casing Cement KO Plug ./ Basis 200% excess in open hole 50% excess in annulus. Top of KO plug 2,300' MD Total Cement Vol: Wash None Spacer None Lead None Tail 70-bbl, 423-sx 15.7-lb/gal AS1 - 0.93 ft;j/sx of tail at BHST = 50°F from SOR, BHCT 65°F estimated by Dowell 4 Draft Permit 10/21/04 · Greater pru. Bay S-213A ML Permit Casing Size 17-% -in 29.7-lb/ft L-80 STL-FJ intermediate casing Basis Top of tail cement 500-ft MD above top of Schrader Ma-sand. 30% excess over gauge. 4' 3 S I Total Cement Vol: Wash 20-bbl Water Spacer 30-bbl~. Ib/gal MudPush space~'/~- Tail 43 bbl, Q -sx 15.8-lb/gal Premium 1.2, t"/sx with D600G - 2gal/sk; D047- 0.2gal ,~D174 - 3% BWOC; B15 .15gal/sk of tail at 4,935-ft Ma: MD Temp BHST == 85°F from SOR, BHCT 90°F estimated by Dowell 7-%" Casing Space Out a) Space 7-%" casing out with pups and long/short joints as required to place the top of a long full joint - 5- 15' above the top of the OBc, OBa and OA sands to allow for the window to be milled just below the top of each sand and in the middle of a full joint of casing. These KOP's may be altered to enhance reservoir contact depending on the angle of intersection of each zone. b) Place 1 RA tag above each window exit. RA tags to be spaced out -40 - 80' above window depth except on the OBd lateral. It will need to be placed 120' above the casing shoe. c) Emergency 7-%" casing slips can be used instead of the 7-%" mandrel hanger if required for space out. 7-%" String Centralizer Placement a) Centralizer size: 7-%" X 8-%" Integral centralizers (7-%" X 8-%" X 17-%") b) Do not run centralizers on the window joints spaced at the top of each sand. c) Centralizers will be run on the first 40 joints to allow for adequate standoff for cement. d) The centralizer program is subject to change pending modeling and hole conditions. 4 ¥2" Slotted Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint, floating between the collars. If any differential sticking is noticed while drilling, it may be necessary to put another centralizer per joint separated by a stop collar. Do not put any centralization on the first two joints above the bent joint. Survey and Logging Program 8-3,4" Hole Section: Surveys will need to be IFR + MS corrected real time Open Hole Drilling: MWD I GR I Res I Den I Neu I PWD (Den Neu recorded only) Open Hole: MDT Pressures & Fluid Samples Cased Hole: USIT Bond Lo onl as contin enc if oor cement ·ob 6-3,4" Hole Section: Surveys will need to be IFR + MS corrected real time Open Hole Drilling: MWD I GR I Res I Azimuthal Den I Neu (Den/Neu recorded only) I AIM I PWD Cased Hole: None 5 Draft Permit 10/21/04 · Greater prue Bay S-213A ML Permit DrillinQ Hazards and ContinQencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control/ Reservoir Pressures: OA 2,141(8.15) 5,052 2,338 (8.9) 5,052 Based on Static and MDT pressures OBa 2,160 (8.15) 5,097 2,352 (8.9) 5,082 Based on Static and MDT pressures OBb 2,175 (8.15) 5,132 2,370 (8.9) 5,122 Based on Static and MDT pressures OBc 2,194 (8.15) 5,177 2,394 (8.9) 5,172 Based on Static and MDT pressures OBd 2,215 (8.15) 5,227 2,414 (8.9) 5,217 Based on Static and MDT pressures II. Hydrates and Shallow gas: A. Gas hydrates are present below S-pad, but have not been a significant issue thus far during S-Pad drilling. If hydrates are encountered follow the recommended practice and apply good drilling operational practices. III. Lost Circulation/Breathing: A. Lost circulation is possible within the Schrader interval due to the reduced pore pressure. A LCM decision tree has been developed to give direction in the event of losses. B. We do not expect breathing on this well as we are above the more prevalent breathing shale's i.e. Seabee. IV. Kick Tolerancellntegrity Testing: A. The 9-%" casing has been cemented to surface. B. The 7-%" flush joint casing will be cemented with 15.8 Ib/gal cement to 500' MD above the Ma sand. C. Integrity Testing: NOTE: If the LOT I FIT is less then the minimum notify the ODE immediately Surface / 8-3,4" Æ 9.2 8.9 12.2 (LOT) Intermediate / 6-3,4" fin' e 9.2 8.9 10.5 (FIT) NOTE: FIT's will only b·· .. ne on the first horizontal lateral due to pressure connectivity between subsequent laterals. NOTE: All LOT I FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casing string /. V. Stuck Pipe A. There could be slight differential sticking across the reservoir while running the slotted liners. Keep the liners moving as much as possible and run one centralizer per joint to help with standoff. VI. Hydrogen Sulfide A. S-Pad is.,J:!Q.l.designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. In Nov. 200385 ppm of H2S was measured at one S-Pad well (S-05A), however all other wells tested below 20 ppm in 2004 and since the reading, S-05A has been shut in. VII. Faults .-/ There is one planned fault crossing and two possible fault crossings while drilling the well. It is also possible to encounter sub-seismic faults along the proposed well path. In the production hole sections, if a fault throws us out of section steer up as fast as possible to determine where we are within the section. This will make it easy to lowside OH sidetrack to get back on course. Fault #1: UG1 5,202' MD Fault #2: O-sands 5,900' MD Fault #3: O-sands 6,825' MD 4,485' TVDss 4,952' TVDss 5,176' TVDss 25' Northeast throw ° - 20' Northeast throw ° - 35' Northeast throw CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Draft Permit 10/21/04 · Greater pru. Bay S-213A ML Permit Drill and Complete Procedure Summary Pre-Rie: Work: 1. Rig up Schlumberger slickline, and drift tubing down to the jet pump fish with drift appropriate for 3.5" chemical/jet cutter. Last well operation was CTU fishing attempts to retrieve the jet pump. Last tag was at 5,314' CTU MD. a. NOTE: If use the chemical cutter it will be required to have the tubing and annulus hydrostatic pressures equalized prior to cutting the tubing. It may be desirable to punch holes in the tubing just below the proposed chemical cut depth in order to allow for pressure equalization. Optional string shot per SOP. 2. RIH w/ chemical/jet cutter. Cut the 3-%" L-80 tubing at approximately 5,250' MD. Chemical cutter is at the discretion of the Wells Group Representative. This cut will not be fished, however a complete cut is critical to successful decompletion. a. NOTE: If chemical cutter is used, then the well should be displaced to seawater prior to making the cut. It is against SOP to use a chemical cutter in diesel. 3. RU and circulate out the diesel through the tubing cut. Once the tubing and annulus are displaced, bullhead sufficient seawater below the jet pump to fill the volume (-20 bbls) to the perfs. Observe 1.5 bpm, 2500 psi max. Previous injectivity tests that were done showed a rate through the jet pump of approximately 1.2 bbls/min @ 2,000 psi surface pressure. Freeze protect down to 2,000' TVD with diesel. a. NOTE: This will leave the well -60 psi under-balanced with the formation. A static BHP was taken on 9/18/04 which gave a reservoir pressure of 2,110 psi @ 5,000' TVDss (8.12 ppg EMW). These pressures assume a diesel gradient of 0.354 psi/ft down to 2,000' TVDss and a seawater gradient of 0.447psi/ft down to 5,000' TVDss. b. NOTE: The well should not be left with methanol as a freeze protect fluid, diesel only. 4. Test all packoffs and tubing hanger seals to 5,000 psi for 30 minutes. MITOA and function test alllockdown screws, repair or replace as needed. a. Verify tubing and annuls pressures and give to rig during the handover. Set a BPV in the tubing hanger and a VR plug in the 7x4-%" IA valve. Secure well. 5. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. DrillinQ RiQ Decompletion Operations: 1. MIRU Doyon 16. Circulate out diesel with seawater. Verify the well is dead. 2. Set TWC. Nipple down tree. Nipple up and test BOPE. / 3. Pull and lay down the 4-W' tubing (planned tubing cut at -5,250'). 4. PU 4,200' of 4" DP and stand back in derrick. MU clean-out BHA with 4" DP and flat bottom mill (or used bit) / boot baskets / etc. RIH to top of tubing stub PU additional 4" DP, circulate and condition wellbore as required. Pump hot oil to remove excess paraffin if needed. 5. MU 7" Halliburton EZSV (running OD 5.5") and RIH and set just above tubing stub @ 5,250'). Set packer and test to 1,000 psi. Dump 10 bbls cement on top of EZSV (-261' of coverage). POOH and LD running tool. 6. MU 7" Halliburton EZSV (running OD 5.5") and RIH and set @ 3,150'. POOH and LD running tool. 7. MU 7" multistring casing cutting assembly and RIH to -2,940' MD and cut casing. Close annular and circulate annulus clean with hot seawater and Safeclean sweep, follow with 9.0 ppg mud. 8. Pull 7" casing and verify cut, circulate and reciprocate casing to clean up remainder of mud/diesel in OA. Remove wellhead pack-off and LD 7" casing. 9. RIH with cement stinger and lay in 70 bbl Class G 15.7 ppg Arctic Set 1 cement plug from EZSV @ 3,150' to 2,300' MD. (Assumes 200% excess in open hole portion from 2,940' to 2,860'.) POOH T~I, 10 - fol ctfrý1Ý'I/~{· DrillinQ RiQ Sidetrack Operations: V 1. MU 8-3,4" directional drilling assembly with MWD/GR/Res/Den/Neu/PWD and a Weatherford Drill-Mill at ±800' from the bit in the HWDP section and RIH to top cement plug. Dress off plug, circulate and condition mud. Directionally drill ahead to TD (Just below the Top OBd) as per directional profile to 6,591' MD /5,227' TVD. /' /' a. Make short trip as needed, work tight spots as seen. 2. Circulate and condition mud at TD. Make sure hole is clean prior to POOH. POOH, LD drilling BHA. 3. RU Schlumberger DPC MDT tool assembly and RIH and acquire pressure and fluid samples as per the town Geologist. POOH and LD assembly. 7 Draft Permit 10/21/04 · Greater pru. Bay S-213A Ml Permit 4. Make cleanout trip to TD and circulate and condition mud as appropriate. 5. MU and run 7-%" 29.7# L-80 STL flush joint casing to TD. Cement in one stage to 500' MD above the Schrader Ma ,- sand. Bump plug with seawater. land casing on mandrel hanger. 6. Clean pits for displacement. Freeze protect 7-%" x 9-%" annulus with dead crude to 2,200' TVD. 7. PU 6-3,4" con~e . nal assembly with MWD/GR/Res/ Azimuthal Den /Neu/PWD and RIH to the float collar. Test the 7- %" casing to ,5 psi for 30 minutes. Displace well over to new Versapro MOBM. Drill out shoe track, circulate and / condition m . Drill 20' of new formation below rathole and perform an FI to 12.0 ppg EMW. 8. Directionally drill ahead to TD geosteering through the OBd to TD at 1 ,14MD / 5,217' TVD (prognosed). Perform ...- wiper trip, circulate and condition mud as required. Displace well to. g SFMOBM as per MI displacement procedures. 9. POOH to near OBc window depth, log up ac~s the OBc, OBa and OA windows. POH LD drilling assembly. 10. MU and run 4-}2" 12.6# L-80 BTC-M slotted tfner with hanger and liner top packer to TD. Position liner top packer 40' ./ below the top OBc sand. POOH and LD liner running assembly. 11. PU the 7-%" whipstock assembly. Set the whiP~Ck on the OBd liner top packer such that the top of the window is ~. near the top of the OBc sand (planned window exit: 6,312' MD). Orient whipstock to highside. Shear off Whipstock. Displace wellbore back to MOBM & mill window. POOH 12. RIH with 6-3,4" drilling assembly (with MWD / GR / Res /æ. zi ,al Den recorded / Neu recorded / AIM) to whipstock. Directionally drill the OBb lateral to TD. Planned TD is 12 'MD. Circulate and condition mud and perform wiper ..../ trip if necessary. Displa~ well to 9.2 ppg SFMOBM as I displacement procedures. POOH. 13. Run and set 4-1h" slotted liner with 6" aluminum billet and Weatherford GS running tool, POOH and LD liner: running .,./' string. 14. RIH with 6-3,4" drilling assembly (with MWD / GR / Res / Azimuthal Den recorded / Neu recorded / AIM) to a~uminum billet in t e open hole. 15. Dis ce ell back to MOBM and KO of aluminum billet and directionally drill the OBc lateral to TD. Planned TD is 12 14 MD. Circulate and condition mud and perform wiper trip if necessary. Displace well to 9.2 ppg SFMOBM as .. I displacement procedures. ~OOH. 16. Pull whipstock #1. Run 4-1h" slotted liner and Baker Hook Hanger, POOH and LD liner running string. Run Baker /' Lateral Entry Module #1 with ZXP liner top packer. Circulate and condition mud, POOH and LD running tools. "'1..... 17. PU the 7-%" whipstock assembly. Set the whips.@ck on the OBc liner top packer such that the top of the window is near the top of the OBa sand (planned window exit: 6,045' MD). Orient whipstock to highside. Shear off of Whipstock, displace well back to MOBM and mill window. POOH / 18. RIH with 6-3,4" drilling assembly (with MWD / GR / Res /. ~hal Den recorded / Neu recorded / AIM) to whipstock. Directionally drill the OBa lateral to TD. Planned TD is r=~.~~MD. Circulate and condition mud and perform wiper trip. Displace well back to SFOBM an~POOH. .~ 19. Pull whipstock ~ ¡Run 4-1h" slotted liner and Baker Hook Hanger, POOH and LD liner running string. Run Baker Lateral Entry Module #2 with ZXP liner top packer. Circulate and condition mud, POOH and LD running tools. 20. PU the 7-%" whipstock assembly. Set the Whif¥'~OCk on the OBa liner top packer such that the top of the window is ./ near the top of the OA sand (planned window exit: 5,918' MD). Orient whipstock to highside. Shear off of Whipstock, displace well back to MOBM and mill window. POOH 21. RIH with 6-3,4" drilling assembly (with MWD / GR / Res /r!)uthal Den recorded / Neu recorded / AIM) to whipstock. ,.- Directionally drill the OA lateral to TD. Planned TD is 1 ,12 ' MD. Circulate and condition mud and perform wiper trip. Displace well baciyo SFOBM and POqf.4,. . 22. Pull whipstock~ Run 4-W' slotted linéf'and hook hanger, POOH and LD liner running string. Run Baker Hook ~ Hanger Lateral Entry Module #3 with ZXP liner top packer. Clean pits for displacement. Displace over to 9.3 ppg KCL brine. POOH. 23. MU 4-W' 12.6# BTM-M, L-80 completion assembly and RIH. See completion schematic for details. Land tubing / hanger and run in lockdown screws. Reverse in brine with Corexit to protect the annulus. 24. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK-1 valve. 25. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 26. Pull two-way check. Freeze protect the well to 2,000' TVD. Install VR plug in 7-%" casing annulus valves. 27. Install BPV. Secure the well and rig down / move off Doyon 16. / Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod / RHC plug. 2. Pull out DCK-1 shear valve, install GL V in all of the other mandrels as per the PE. 8 Draft Permit 10/21/04 · POS,T RIG.- COMPLETION.EE FMC 4.-1/16' 15M . 0 1<8 elev (N-9ES) 64.4' S 213A L 1 L2 L3 & L4· ELLHEAD FM C G!!n 5 System - . ,., " 11" 15M csgJlead wi 7-518" mandrel hanger & packoff I ~'¡ew Plan I{B .elev 16)::: 619' 11'xll',5M tbgspoolwl 11" x 4-112" tubing hanger with controllíne ports 1 "X 4-1116" Adaptor Flange 20' X 34" 215.5 Iblft, A53 ERW InSulated 109' ~ Phoenix Pressure ..... / Gauge !f!'Y with eont~ lines to surface 1011212004 DATE ........ Halliburton X-Nipple (3.813"10) 12,200' TVD I Junction Specifications: Junction ID through LEM Module without dlverte :3 .65" Cameo 4-1!2K x 1" KBG-2 GtM's / 4.S" Baker sliding sleeve with 3.813"10 .... 9-518",40# l-80 BTC Csg @ 2.,859' MD 4-112",12.6 Iblft, L~80,BTC-M Tubing Coup 0052 Drift/ID . 3833"/3958' .- 7-Sl8u X 5-1/2~ Baker PRM Packer REV BY MlK TRIOLO Halliburton X-Nipple (3.813"ID) 4.5"WlEG I 5,870' MD 9.2 PPG Versapro MOBM below Completion OA Lateral 15,918'.12,128'1 6-3/4" Open hole Horizontal Laterals 4-1/2",12.6 Ib/ft, L-80, BTC-M Liners Coup OD 52 DriftfID3,833"/3.958" OBa Lateral 16,045'.12,139'1 7-5/8",29 7#, L-80, STL-PJ Casing Drift 6 75" Casing ID. 6.875" RA Tag TBD 5,868' MD Wjndow In 7·5/8" ca ,918' MD Well Inclination @ Window" 62" Top Baker lEM Assembiy @ 5,995' M 0 Window in 7·5/8' casing@ 6.U'15'MD WeUJncllnation @ Window:::: 6So Top Baker lEM Assembly @ 6.262· M D \Nlndow in 7-5/8' casing@ 6,312'MD Well Inclination @ Window:::: 7~' OBd Lateral / 16.591'.12,1491 7-518" Casing Shoe @ 6,591' MD COMM ENTS G level 3 Multi-lateral, 4-112' Gl Completion API 0: 50-029-22993-00 50-029-22993-xJ( 50·029-22993 -xx 50·029-22993·xJ( 50-029·22993-xx PO LARIS WELL: S-213A ML ¢? 0 0 CO ~ 4000 II aJ ro c.> Cf) 0 ~ 4800 Schlumberger WELL FIELD Prudhoe Bay Unit - WOA STRUCTURf S-P AD S-213A (P4) MagOllticP!lramelers Model: BGGM 2004 SufaceLpeaüon Date: Nøvembér15,2004 Lat: N102119.849 FS: 57608.7nT Lon: W14922.959 NA027 Alaska stale Planas, Zone 04, US Feet Northing: 5980549.84 nus Grid Cony: +0.90963906' Eastlng: 618929.96 ruJS SCale Fact: 0.9999160676 MlsceUiIrI9OU$ Slot: 8-213 Plan: 5-213A (P4) oed Dip: 80.844' MagDec: +24.845' TVO Ref: Rotary Table (61.90 I't &boY. MSl) SNyDate: Oetober01,2004 o 800 7200 1600 2400 3200 4000 4800 5600 6400 2400 " """ .. ...... . . . , . . . . . ....'!".................................'j"...................····..·········r..···················....·········r·....···......········......······1·......·······..·..······....·······1···..··········..·····..···..·..···..1···..·..········....········..·..···1·..·..·····..····....···········..···1·..· 2400 w·=~:~r:':"·······I··········I·········L........'.........l........j.........I.........J. Ender ¡ ¡ ! ! ¡ ¡ ! ! . ~ ,-,,, ,", ",--- ,-,,, '4' "'" ",-",,,,,,,,,,,, F"'--" ,,- ,-, "'--1' "'-'-'"'"",-'-'-!"',,''''',,,,, ,-, "" r -,- '-'"'''''--'''1''''''''-'-'-''''''''1''' "'" ""'"'.'''-''1''' . 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PI ¡ Crv6l100 I \ : : Crv6/100: EndCrv j j ¡ ¡ ¡ T C 9 S.213A OBd TgI 2 End or- ¡ S.213A OB~ TgI 4 ¡ ¡ tmIL~~':LL¡L···¡~::'~~:1 5600 . 3200 .:.·.i,·J..·...·w,·.·.·,$.',Il.,·.. saoo o 800 1600 2400 3200 4000 4800 Vertical Section (ft) Azim = 196.54°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-W 5600 6400 7200 ...Ll S-213A (P4) -- Model: BGGM 2004 Dip: 80.844' Mag Dee: +24.845' ^ ^ ^ z ¢? 0" o o ..- ~ ..- II Q) õj () en en v v v . . Schlumberger FIElD STRUCTURE S-PAD Prudhoe Bay Unit - WOA I Sutfacelocation Date· NcYember15,2004 lat: N702119.849 FS· 57608.7 nT Lon: W149 2 2.959 NAD27 Alaska State Planes, Zone04,US Feet Northing 5980549.84 nus Grid Corw; +0.90963900' Easting" 618929.96ftUS Scale Fact: 0.9999160676 -- Slot: S-213 Plan: S-213A(p4)Q8d -4000 -1000 o -3000 -2000 o ~ T..1n Survey ¡ndow KOP 4/100 .-/ -1000 . . r·····...····.....···......·······rëáï<Öp····· .. :IV 4.~ ~)i ( -2000 .U.....................,..............H.............. -3000 : Cry 6I1~0 ¡ ¡ i 5-213A ~Bd Tgt 2 ¡ ¡ +_H_¡¡~i:::'~:.r;::-l---rH--- ~ ... C~ 61100 ~ : ¡ ~5-t13AOBdTgt3 I I :- .": ; : .~....<,...........,.._.......... ........... ....... ..........".H.«.._.......<.......~.."...........................,. Cry 61100 5-213f OBd Tgt 4 End Crv ~ ........,.............. S·213A (P4) OBd ·r··'·····,..····,····,,····,"'··..'lv.'" ··········,·················"r···"·····,,····,',·········,,····"r·····',···,·,······ ................;..........'..H.....' -4000 -5000 .~...... -6000 ,............,........ -7000 ------- -4000 -2000 -1000 <<< W Scale = 1(in):1000(ft) E >>> o -3000 TVDRef: RxltafyTabIe(61,90fI.~MSl) SNyDatø: Odober01,2004 o -1000 -2000 -3000 -4000 -5000 -6000 -7000 S-213 Actual Surveys Schlumberger Report Dete: September 27,2004 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertlcel Section Azimuth: 195.390' Field: Prudhoe Bay Unit - WOA Vertlcel Section Origin: N 0.000 It, E 0.000 It Structure / Slot: S-PAO / S-213 TVD Reference Detum: Rotary Table Well: S·213 TVD Reference Elevetlon: 59.9 It relative to MSL Borehole: Plan S-213A OBb UWVAPI#: 500292299301 Magnetic Declination: 24.953' Survey Name / Date: S-213A (P3) / July 29, 2004 Total Field Strength: 57589.741 nT lort I AHD / DDI/ ERD ratio: 206.793' /14098.00 ft/6.831/2.691 Magnetic Dip: 80.867' Grid Coordinate System: NA027 Alaska State Pianes, Zone 04, US Feet Declination Date: September 30, 2004 Location LattLong: N 70.35551358, W 149.03415537 Magnetic Declination Model: BGGM 2004 Location Grid NIE Y/x: N 5980549.840 ftUS, E 618929.960 ftUS North Reference: True North . Grid Convergence Angla: +0.90963906' Total Corr Mag North -> True North: +24.953' Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head I Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Eastlng Latllude Longllude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (deg/100 It) ( deg) ( degl100 It ) ( degl100 It) (ltUS) (ltUS) Projected-Up 0.00 0.00 297.52 -59.90 0.00 -0.02 0.00 0.05 -0.10 0.00 -62.48M 0.00 0.00 5980549.89 618929.86 N 70.35551372 W 149.03415617 100.00 0.05 297.52 40.10 100.00 -0.03 0.05 0.07 -0.14 0.05 -62.48M 0.05 0.00 5980549.91 618929.82 N 70.35551378 W 149.03415652 155.00 0.08 297.52 95.10 155.00 -0.05 0.11 0.10 -0.20 0.05 -152.28M 0.05 0.00 5980549.94 618929.76 N 70.35551386 W 149.03415697 200.00 0.10 207.72 140.10 200.00 -0.01 0.17 0.08 -0.24 0.29 -170.30M 0.05 -199.55 5980549.92 618929.71 N 70.35551380 W 149.03415735 233.07 0.19 189.70 173.17 233.07 0.07 0.25 0.00 -0.27 0.29 -148.56M 0.26 -54.50 5980549.84 618929.69 N 70.35551358 W 149.03415754 300.00 0.25 211.44 240.10 300.00 0.32 0.51 -0.23 -0.36 0.15 -142.82M 0.09 32.49 5980549.60 618929.60 N 70.35551294 W 149.03415831 326.61 0.28 217.18 266.71 326.61 0.44 0.63 -0.33 -0.43 0.15 -168.40M 0.11 21.56 5980549.50 618929.53 N 70.35551266 W 149.03415888 400.00 0.42 191.60 340.10 400.00 0.87 1.07 -0.74 -0.59 0.29 -171.55M 0.20 -34.86 5980549.09 618929.38 N 70.35551155 W 149.03416020 415.33 0.46 188.45 355.43 415.33 0.99 1.19 -0.86 -0.62 0.29 147.48M 0.24 -20.53 5980548.97 618929.36 N 70.35551123 W 149.03416037 500.00 0.28 147.48 440.10 500.00 1.47 1.71 -1.37 -0.56 0.37 140.23M -0.22 -48.38 5980548.46 618929.43 N 70.35550984 W 149.03415988 509.57 0.27 140.23 449.67 509.57 1.49 1.76 -1.40 -0.53 0.37 136.87M -0.06 -75.79 5980548.43 618929.45 N 70.35550974 W 149.03415966 600.00 0.35 136.87 540.09 599.99 1.76 2.25 -1.77 -0.20 0.09 136.82M 0.09 -3.71 5980548.07 618929.78 N 70.35550875 W 149.03415703 601.89 0.35 136.82 541.98 601.88 1.77 2.26 -1.78 -0.20 0.09 110.75M 0.09 -2.86 5980548.06 618929.79 N 70.35550872 W 149.03415697 694.52 0.40 110.75 634.61 694.51 1.94 2.86 -2.10 0.30 0.19 111.45M 0.05 -28.14 5980547.75 618930.29 N 70.35550785 W 149.03415294 700.00 0.38 111.45 640.09 699.99 1.95 2.89 -2.11 0.33 0.31 142.58M -0.29 12.69 5980547.73 618930.33 N 70.35550781 W 149.03415266 787.54 0.15 142.58 727.63 787.53 2.05 3.29 -2.31 0.68 0.31 131.37M -0.27 35.57 5980547.54 618930.67 N 70.35550727 W 149.034. 800.00 0.17 131.37 740.09 799.99 2.07 3.33 -2.33 0.70 0.29 98.80M 0.14 -89.94 5980547.52 618930.70 N 70.35550720 W 149.034 882.84 0.36 98.80 822.93 882.83 2.09 3.70 -2.45 1.05 0.29 98.72M 0.23 -39.32 5980547.40 618931.05 N 70.35550687 W 149.034 900.00 0.37 98.72 840.09 899.99 2.08 3.81 -2.47 1.16 0.08 98.44M 0.08 -0.45 5980547.39 618931.16 N 70.35550683 W 149.03414597 976.11 0.43 98.44 916.20 976.10 2.01 4.34 -2.55 1.68 0.08 98.39M 0.08 -0.37 5980547.32 618931.68 N 70.35550661 W 149.03414169 1000.00 0.46 98. 39 940.09 999.99 1.99 4.53 -2.58 1.87 0.11 98.28M 0.11 -0.20 5980547.29 618931.87 N 70.35550654 W 149.03414021 1068.74 0.53 98.28 1008.82 1068.72 1.92 5.12 -2.66 2.45 0.11 91.33M 0.11 -0.16 5980547.22 618932.45 N 70.35550630 W 149.03413546 1100.00 0.53 91.33 1040.08 1099.98 1.86 5.41 -2.69 2.74 0.21 78.60M 0.01 -22.22 5980547.20 618932.74 N 70.35550624 W 149.03413312 1160.21 0.56 78.60 1100.29 1160.19 1.66 5.98 -2.64 3.31 0.21 74.46M 0.04 -21.15 5980547.26 618933.31 N 70.35550638 W 149.03412850 1200.00 0.65 74.46 1140.08 1199.98 1.46 6.40 -2.54 3.72 0.25 70.45M 0.22 -10.41 5980547.36 618933.72 N 70.35550665 W 149.03412519 1252.93 0.77 70.45 1193.00 1252.90 1.10 7.05 -2.34 4.34 0.25 70.35M 0.23 -7.57 5980547.57 618934.34 N 70.35550719 W 149.03412013 1300.00 1.01 70.35 1240.07 1299.97 0.68 7.79 -2.09 5.03 0.51 70.29M 0.51 -0.21 5980547.83 618935.02 N 70.35550786 W 149.03411453 1346.97 1.25 70.29 1287.03 1346.93 0.15 8.71 -1.78 5.90 0.51 74.08M 0.51 -0.13 5980548.15 618935.89 N 70.35550871 W 149.03410745 1400.00 1.56 74.08 1340.04 1399.94 -0.56 10.01 -1.39 7.14 0.62 76.02M 0.59 7.15 5980548.57 618937.12 N 70.35550979 W 149.03409738 1439.11 1.80 76.02 1379.14 1439.04 -1.14 11.16 -1.09 8.25 0.62 75.37M 0.60 4.96 5980548.88 618938.23 N 70.35551059 W 149.03408837 1500.00 1.55 75.37 1440.00 1499.90 -2.02 12.94 -0.65 9.98 0.41 74.91M -0.41 -1.06 5980549.35 618939.94 N 70.35551179 W 149.03407436 W€IIDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\Plan S-213A OBb\S-213A (P3) Generated 10/7/2004 8:56 AM Page 1 of 2 1533.98 1.41 74.91 1473.97 1533.87 -2.46 13.82 -0.43 10.82 0.41 70.63M -0.41 -1.36 5980549.58 618940.79 N 70.35551241 W 149.03406747 1600.00 0.95 70.63 1539.97 1599.87 -3.18 15.18 -0.04 12.12 0.72 66.98M -0.70 -6.48 5980550.00 618942.08 N 70.35551348 W 149.03405694 1629.58 0.74 66.98 1569.55 1629.45 -3.44 15.61 0.12 12.53 0.72 -99.47M -0.69 -12.34 5980550.16 618942.48 N 70.35551390 W 149.03405364 1700.00 1.68 260.53 1639.96 1699.86 -3.29 16.49 0.13 11.93 3.42 -100.17M 1.34 -236.36 5980550.16 618941.88 N 70.35551393 W 149.03405853 1722.73 2.46 259.23 1662.68 1722.58 -2.93 17.31 -0.02 11.12 3.42 -105.10M 3.42 -5.74 6980550.00 618941.08 N 70.35551353 W 149.03406509 1800.00 5.70 254.90 1739.74 1799.64 -0.25 22.81 -1.33 5.78 4.21 -3.27G 4.20 -5.60 5980548.60 618935.76 N 70.35550995 W 149.03410843 1813.71 6.28 254.60 1753.38 1813.28 0.48 24.24 -1.71 4.40 4.21 63.80G 4.21 -2.20 5980548.20 618934.39 N 70.35550892 W 149.03411964 1863.29 6.40 256.71 1802.65 1862.55 3.19 29.71 -3.06 -0.90 0.53 -93.22G 0.24 4.26 5980546.76 618929.10 N 70.35550522 W 149.03416271 1900.00 6.39 253.65 1839.14 1899.04 5.25 33.80 -4.11 -4.86 0.93 -90.18G -0.03 -8.34 5980545.66 618925.17 N 70.35550236 W 149.03419480 1906.95 6.39 253.07 1846.04 1905.94 5.66 34.58 -4.33 -5.60 0.93 -108.50G 0.00 -8.34 5980545.42 618924.43 N 70.35550175 W 149.03420081 2000.00 6.09 240.34 1938.55 1998.45 11.92 44.65 -8.28 -14.84 1.52 -95.84G -0.32 -13.68 5980541.33 618915.25 N 70.35549096 W 149.03427587 2000.19 6.09 240.31 1938.74 1998. 64 11.93 44.67 -8.29 -14.86 1.52 -164.55G -0.15 -14.24 5980541.32 618915.24 N 70.35549093 W 149.03427601 2094.74 5.63 239.Q1 2032.79 2092.69 18.84 54.32 -13.16 -23.19 0.51 -154.29G -0.49 -1.37 5980536.31 618906.98 N 70.35547762 W 149.03434367 2100.00 5.61 238.93 2038.03 2097.93 19.22 54.84 -13.43 -23.63 0.33 -154.21G -0.29 -1.45 5980536.04 618906.55 N 70.35547690 W 149.03434726 2187.00 5.36 237.61 2124.63 2184.53 25.31 63.16 -17.80 -30.71 0.33 -137.89G -0.29 -1.52 5980531.56 618899.54 N 70.35546495 W 149.03440472 2200.00 5.33 237.30 2137.57 2197.47 26.21 64.37 -18.45 -31.73 0.33 -137.58G -0.25 -2.41 5980530.89 618898.53 N 70.35546317 W 149.03441301 2281.60 5.13 235.24 2218.83 2278.73 31.83 71.80 -22.58 -37.91 0.33 15.75G -0.24 -2.52 5980526.66 618892.41 N 70.35545190 W 149.03446323 2300.00 5.51 236.35 2237.15 2297.05 33.13 73.51 -23.54 -39.33 2.14 14.64G 2.06 6.04 5980525.68 618891.02 N 70.35544928 W 149.034. 2374.88 7.07 239.64 2311.58 2371.48 39.14 81.71 -27.86 -46.29 2.14 11.55G 2.08 4.39 5980521.25· 618884.12 N 70.35543747 W 149.034 2400.00 8.42 241.52 2336.47 2396.37 41.53 85.10 -29.52 -49.24 5.47 9.69G 5.37 7.47 5980519.55 618881.19 N 70.35543294 W 149.034 2469.31 12.17 244.54 2404.65 2464.55 49.83 97.48 -35.08 -60.31 5.47 -2.24G 5.41 4.36 5980513.81 618870.22 N 70.35541775 W 149.03464505 2500.00 14.20 244.22 2434.53 2494.43 54.42 104.48 -38.11 -66.62 6.63 -1.93G 6.63 -1.06 5980510.68 618863.96 N 70.35540947 W 149.03469630 2502.80 14.39 244.19 2437.24 2497.14 54.88 105.17 -38.41 -67.24 6.63 -9.13G 6.63 -0.90 5980510.37 618863.34 N 70.35540865 W 149.03470135 2532.40 15.76 243.38 2465.82 2525.72 59.99 112.87 -41.81 -74.14 4.68 -8.59G 4.63 -2.74 5980506.86 618856.49 N 70.35539935 W 149.03475742 2562.39 17.56 242.48 2494.55 2554.45 65.80 121.46 -45.73 -81.80 6.06 -11.09G 6.00 -3.00 5980502.82 618848.90 N 70.35538866 W 149.03481957 2591.48 19.43 241.38 2522.14 2582.04 72.15 130.69 -50.07 -89.94 6.54 ·20.24G 6.43 -3.78 5980498.35 618840.84 N 70.35537678 W 149.03488567 2600.00 19.55 241.25 2530.17 2590.07 74.12 133.53 -51.44 -92.43 1.47 ·20.12G 1.38 -1.52 5980496.95 618838.36 N 70.35537306 W 149.03490591 2627.65 19.93 240.84 2556.20 2616.10 80.65 142.87 -55.96 -100.60 1.47 6.67G 1.38 -1.48 5980492.30 618830.27 N 70.35536070 W 149.03497226 2655.42 20.53 241.04 2582.25 2642.15 87.37 152.48 -6Q.62 -109.00 2.17 2.50G 2.16 0.72 5980487.50 618821.95 N 70.35534796 W 149.03504042 2686.50 21.45 241.15 2611.27 2671.17 95.15 163.61 -66.00 -118.74 2.96 -25.75G 2.96 0.35 5980481.97 618812.29 N 70.35533326 W 149.03511955 2700.00 21.74 240.77 2623.82 2683.72 98.63 168.58 -68.41 -123.09 2.40 -25.39G 2.17 -2.82 5980479.49 618807.99 N 70.35532667 W 149.03515483 2718.29 22.14 240.27 2640.79 2700.69 103.45 175.41 -71.78 -129.04 2.40 -33.95G 2.17 -2.73 5980476.03 618802.09 N 70.35531748 W 149.03520313 2749.49 23.21 238.46 2669.58 2729.48 112.11 187.44 -77.91 -139.38 4.09 -34.67G 3.43 -5.80 5980469.73 618791.84 N 70.35530073 W 149.03528714 2797.96 24.47 236.38 2713.91 2773.81 126.66 207.03 -88.46 -155.88 3.12 0.89G 2.60 -4.29 5980458.92 618775.52 N 70.35527190 W 149.03542112 2800.00 24.54 236.38 2715.77 2775.67 127.30 207.87 -88. 93 -156.59 3.44 0.89G 3.44 0.13 5980458.44 618774.82 N 70.35527062 W 149.03542684 rie-In Survey 2856.12 26.47 236.45 2766.42 2826.32 145.53 232.04 -102.30 -176.72 3.44 8.17G 3.44 0.12 5980444.76 618754.90 N 70.35523410 W 149.03559029 - WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\Plan S-213A OBb\S-213A (P3) Generated 10/7/20048:56 AM Page 2 of 2 S-213A (P4) Proposal Schlumberger Report Date: October 1, 2004 Survey / DLS Computation Method: Minimum Curvature / Lubinski I Client: BP Exploration Alaska Vertical Section Azimuth: 196.54' ~Ca tav Field: Prudhoe Bay Unit - WOA st Vertical Section Origin: N 0.000 It, E 0.000 It use Structure / Slot: S·PAD / S·213 ørty U 1VD Reference Datum: Rotary Table Well: S-213 Feaslbm I 1VD Reference Elevation: 61.90 It relative to MSL Borehole: Plan S-213A OBd Sea Bed / Ground Level Elevation: 35.90 It relative to MSL ÌßyC/ V1 (~ UWIiAPI#: 500292299301 Magnetic Declination: 24.845' Survey Name I Date: S-213A (P4) OBd / November 15, 2004 Total Field Strength: 57608.708 nT fortI AHD / DDiI ERD ratio: 186.353' /8540.802 It /6.567 /1.637 Magnetic Dip: 80.844' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 15, 2004 Location Lat/long: N 70.35551358, W 149.03415537 Magnetic Declination Model: BGGM 2004 Location Grid NIE YIX: N 5980549.840 ItUS, E 618929.960 nus North Reference: True North . Grid Convergence Angle: +0.90963906' Total Corr Mag North .) True North: +24.845' Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head Comr1e!lts Measured I Inclination I Azimuth I Sub·Sea 1VD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting Latitude Longitude ) Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (deg/100 It) (deg) (deg/100 It) (deg/100 It) (ltUS) (ltUS) Tie-In Survey 2856.62 26.4 7 236.45 2764.92 2826.82 148.37 232.04 -102.30 -176.72 3.44 8.17G 3.44 0.12 5980444.76 618754.90 N 70.35523410 W 149.03559029 Window KOP 4/100 2870.00 27.23 236.69 2776.85 2838.75 153.00 238.08 -105.63 -181.76 5.73 -1.81G 5.67 1.78 5980441.35 618749.91 N 70.35522501 W 149.03563124 2900.00 28.43 236.61 2803.38 2865.28 163.71 252.08 -113.33 -193.46 4.00 -1.74G 4.00 -0.27 5980433.4 7 618738.34 N 70.35520397 W 149.03572623 SV2 2925.84 29.46 236.54 2826.00 2887.90 173.29 264.59 -120.22 -203.90 4.00 -1.68G 4.00 -0.25 5980426.41 618728.01 N 70.35518515 W 149.03581099 3000.00 32.43 236.38 2889.59 2951.49 202.53 302.72 -141.28 -235.68 4.00 -1.55G 4.00 -0.22 5980404.85 618696.58 N 70.35512759 W 149.03606902 3100.00 36.43 236.20 2972.06 3033.96 245.99 359.24 -172.66 -282.69 4.00 -1.40G 4.00 -0.18 5980372.73 618650.07 N 70.35504188 W 149.03645079 3200.00 40.42 236.05 3050.39 3112.29 293.88 421.38 -207.29 -334.28 4.00 -1.28G 4.00 -0.15 5980337.29 618599.04 N 70.35494726 W 149.03686965 End Crv 3295.4 7 44.24 235.93 3120.95 3182.85 343.52 485.66 -243.25 -387.56 4.00 O.OOG 4.00 -0.13 5980300.49 618546.34 N 70.35484902 W 149.03730227 SV1 3340.21 44.24 235.93 3153.00 3214.90 367.64 516.87 -260.74 -413.42 0.00 O.OOG 0.00 0.00 5980282.60 618520.77 N 70.35480124 W 149.03751221 UG4 3802.24 44.24 235.93 3484.00 3545.90 616.78 839.23 -441.33 -680.44 0.00 O.OOG 0.00 0.00 5980097.80 618256.67 N 70.35430783 W 149.03968021 UG4A 3838.53 44.24 235.93 3510.00 3571.90 636.35 864.55 -455.51 -701.41 0.00 O.OOG 0.00 0.00 5980083.29 618235.93 N 70.35426907 W 149.03985050 UG3 4320.11 44.24 235.93 3855.00 3916.90 896.02 1200.54 -643.75 -979.73 0.00 O.OOG 0.00 0.00 5979890.68 617960.66 N 70.35375475 W 149.04211008 UG1 5094.82 44.24 235.93 4410.00 4471.90 1313.76 1741.05 -946.55 -1427.45 0.00 O.OOG 0.00 0.00 5979580.83 617517.84 N 70.35292731 W 149.04574482 Ma 5435.41 44.24 235.93 4654.00 4715.90 1497.41 1978.68 -1079.68 -1624.29 0.00 O.OOG 0.00 0.00 5979444.61 617323.15 N 70.35256351 W 149.04734_ Mb1 5506.60 44.24 235.93 4705.00 4766.90 1535.80 2028.35 -1107.50 -1665.43 0.00 O.OOG 0.00 0.00 5979416.13 617282.46 N 70.35248747 W 149.04767 Crv 4/100 5515.05 44.24 235.93 4711.06 4772.96 1540.36 2034.24 -1110.81 -1670.32 0.00 -23.61G 0.00 0.00 5979412.75 617277.63 N 70.35247844 W 149.04771633 Mb2 5570.38 46.28 234.70 4750.00 4811.90 1571.00 2073.54 -1133.18 -1702.63 4.00 -22.75G 3.68 -2.22 5979389.88 617245.68 N 70.35241732 W 149.04797860 5600.00 47.37 234.08 4770.27 4832.17 1588.05 2095.14 -1145.75 -1720.19 4.00 -22.32G 3.69 -2.10 5979377.02 617228.33 N 70.35238294 W 149.04812114 Me 5683.30 50.4 7 232.44 4825.00 4886.90 1638.39 2157.92 -1183.32 -1770.48 4.00 -21.24G 3.71 -1.97 5979338.66 617178.64 N 70.35228028 W 149.04852938 5700.00 51.09 232.13 4835.56 4897.46 1648.89 2170.86 -1191.24 -1780.71 4.00 -21.05G 3.73 -1.86 5979330.59 617168.53 N 70.35225865 W 149.04861247 Na 5789.99 54.46 230.54 4890.00 4951.90 1707.74 2242.50 -1236.02 -1836.64 4.00 -20.09G 3.75 -1.76 5979284.93 617113.33 N 70.35213628 W 149.04906643 5800.00 54.84 230.37 4895.79 4957.69 1714.51 2250.66 -1241.21 -1842.93 4.00 -19.99G 3.76 -1.68 5979279.64 617107.12 N 70.35212208 W 149.04911751 Nb 5816.11 55.44 230.10 4905.00 4966.90 1725.51 2263.89 -1249.67 -1853.10 4.00 -19.83G 3.76 -1.66 5979271.02 617097.09 N 70.35209897 W 149.04920001 Ne 5883.53 57.98 229.03 4942.00 5003.90 1772.76 2320.24 -1286.22 -1895.98 4.00 -19.24G 3.77 -1.60 5979233.79 617054.80 N 70.35199908 W 149.04954811 5900.00 58.60 228.77 4950.65 5012.55 1784.59 2334.25 -1295.43 -1906.54 4.00 -19.11G 3.78 -1.54 5979224.42 617044.39 N 70.35197391 W 149.04963380 Well Design Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-213\S-213\Plan S-213A OBd\S-213A (P4) OBd Generated 10/1/20042:10 PM Page 1 of 3 I Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting I Latitude Longitude "I Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (deg/100 It) (deg) (deg/100 It) (deg/100 It) (ltUS) (ltUS) OA KOP 5918.12 59.29 228.50 4960.00 5021.90 1797.74 2349.77 -1305.69 -1918.19 4.00 -18.97G 3.78 -1.52 5979213.98 617032.90 N 70.35194588 W 149.04972834 OA 5978.93 61.59 227.60 4990.00 5051.90 1842.84 2402.67 -1341.06 -1957.52 4.00 -18.52G 3.79 -1.48 5979177.99 616994.14 N 70.35184924 W 149.05004762 6000.00 62.39 227.30 4999.89 5061.79 1858.80 2421.26 -1353.64 -1971.23 4.00 -18.38G 3.79 -1.43 5979165.20 616980.64 N 70.35181486 W 149.05015882 OBa KOP 6044.66 64.09 226.67 5020.00 5081.90 1893.18 2461.14 -1380.84 -2000.38 4.00 -18.10G 3.80 -1.40 5979137.54 616951.92 N 70.35174052 W 149.05039545 OBa 6079.84 65.43 226.19 5035.00 5096.90 1920.77 2492.96 -1402.77 -2023.43 4.00 -17.89G 3.80 -1.37 5979115.24 616929.23 N 70.35168059 W 149.05058255 6100.00 66.20 225.92 5043.26 5105.16 1936.77 2511.35 -1415.54 -2036.67 4.00 -17.78G 3.81 -1.34 5979102.27 616916.19 N 70.35164571 W 149.05069002 OBb 6169.96 68.86 225.00 5070.00 5131.90 1993.36 2576.00 -1460.88 -2082.74 4.00 -17.43G 3.81 -1.31 5979056.21 616870.85 N 70.35152179 W 149.05106395 6200.00 70.01 224.62 5080.55 5142.45 2018.13 2604.12 -1480.83 -2102.56 4.00 -17.30G 3.82 -1.28 5979035.94 616851.35 N 70.35146727 W 149.05122481 6300.00 73.83 223.38 5111.58 5173.48 2102.47 2699.16 -1549.21 -2168.58 4.00 -16.91G 3.82 -1.24 5978966.53 616786.43 N 70.35128042 W 149.05176057 OBc 6312.47 74.31 223.23 5115.00 5176.90 2113.17 2711.15 -1557.94 -2176.80 4.00 -16.87G 3.83 -1.21 5978957.68 616778.35 N 70.35125658 W 149.05182732 6400.00 77.66 222.19 5136.19 5198.09 2189.38 2796.07 -1620.33 -2234.39 4.00 -16.62G 3.83 -1.19 5978894.38 616721.76 N 70.35108607 W 149.05229471 6500.00 81.50 221.03 5154.28 5216.18 2278.45 2894.40 -1693.85 -2299.69 4.00 -16.41G 3.84 -1.16 5978819.84 616657.65 N 70.35088516 W 149.05282_ OBd 6591.13 85.00 220.00 5164.99 5226.89 2361.12 2984.88 -1762.64 -2358.47 4.00 -16.29G 3.84 -1.13 5978750.14 616599.97 N 70.35069720 W 149.05330 S-213A Csg Tgt 6591.24 85.00 220.00 5165.00 5226.90 2361.22 2984.99 -1762.72 -2358.54 4.00 O.OOG 3.84 -1.13 5978750.05 616599.90 N 70.35069696 W 149.05330 7" Csg Pt 6591.36 85.00 220.00 5165.01 5226.91 2361.33 2985. 11 -1762.81 -2358.62 0.00 O.OOG 0.00 0.00 5978749.96 616599.83 N 70.35069672 W 149.05330282 KOP Cry 6/100 6611.24 85.00 220.00 5166.74 5228.64 2379.50 3004.91 -1777.99 -2371.35 0.00 30.58G 0.00 0.00 5978734.59 616587.34 N 70.35065526 W 149.05340614 End Cry 6651.52 87.08 221.23 5169.52 5231.42 2416.19 3045.10 -1808.49 -2397.51 6.00 O.OOG 5.17 3.06 5978703.68 616561.67 N 70.35057191 W 149.05361841 Cry 6/100 6784.15 87.08 221.23 5176.28 5238.18 2536.54 3177.56 -1908.11 -2484.81 0.00 -70.68G 0.00 0.00 5978602.69 616475.97 N 70.35029968 W 149.05432689 6800.00 87.40 220.33 5177.04 5238.94 2550.97 3193.39 -1920.09 -2495.15 6.00 -70.63G 1.99 -5.67 5978590.55 616465.82 N 70.35026693 W 149.05441079 6900.00 89.40 214.67 5179.84 5241.74 2644.27 3293.34 -1999.36 -2555.98 6.00 -70.47G 2.00 -5.66 5978510.33 616406.26 N 70.35005032 W 149.05490435 S-213A OSc rgt 1 6930.12 90.00 212.97 5180.00 5241.90 2673.03 3323.46 -2024.38 -2572. 74 6.00 -81.78G 2.01 -5.65 5978485.05 616389.90 N 70.34998195 W 149.05504037 7000.00 90.60 208.82 5179.63 5241.53 2740.72 3393.34 -2084.33 -2608.61 6.00 -81.80G 0.86 -5.94 5978424.54 616354.99 N 70.34981814 W 149.05533141 7100.00 91.45 202.88 5177.85 5239.75 2839.34 3493.32 -2174.27 -2652.19 6.00 -81.91G 0.85 -5.94 5978333.93 616312.85 N 70.34957239 W 149.05568488 7200.00 92.28 196.93 5174.59 5236.49 2939.07 3593.27 -2268.20 -2686.21 6.00 -82.10G 0.83 -5.94 5978239.48 616280.33 N 70.34931575 W 149.05596075 End Cry 7261.10 92.78 193.30 5171.88 5233.78 3000.08 3654.31 -2327.12 -2702,12 6.00 O.OOG 0.82 -5.95 5978180.32 616265.35 N 70.34915477 W 149.05608978 Cry 6/100 7850.58 92.78 193.30 5143.26 5205.16 3587.92 4243.09 -2900.11 -2837.56 0.00 -101.48G 0.00 0.00 5977605.30 616139.04 N 70.34758927 W 149.05718745 7900.00 92.19 190.39 5141.12 5203.02 3637.12 4292.4 7 -2948.43 -2847.70 6.00 -101.61G -1.20 -5.88 5977556.83 616129.67 N 70.34745726 W 149.05726956 S-213A OSd 1"gt 2 7932.16 91.80 188.50 5140.00 5201.90 3669.02 4324.61 -2980.13 -2852.97 6.00 -101.04G -1.21 -5.88 5977525.05 616124.90 N 70.34737064 W 149.05731227 End Cry 7996.74 91.05 184.70 5138.39 5200.29 3732.59 4389.17 -3044.25 -2860.39 6.00 O.OOG -1.15 -5.89 5977460.83 616118.50 N 70.34719547 W 149.05737227 Cry 6/100 8714.35 91.05 184.70 5125.18 5187.08 4434.81 5106.66 -3759.34 -2919.14 0.00 -151.75G 0.00 0.00 5976744.96 616071.12 N 70.34524186 W 149.05784684 S-213A OSci -(gt 3 8734.31 90.00 184.13 5125.00 5186.90 4454.32 5126.61 -3779.23 -2920.67 6.00 -151.80G -5.29 -2.84 5976725.05 616069.90 N 70.34518751 W 149.05785924 End Cry 8754.08 88.95 183.57 5125.18 5187.08 4473.60 5146.38 -3798.95 -2922.00 6.00 O.OOG -5.29 -2.84 5976705.31 616068.89 N 70.34513363 W 149.05786. Cry 6/100 10021.53 88.95 183.57 5148.31 5210.21 5708.51 6413.62 -5063.74 -3000.89 0.00 -92.36G 0.00 0.00 5975439.54 616010.09 N 70.34167826 W 149.05850 10100.00 88.76 178.86 5149.87 5211.77 5784.16 6492.08 -5142.15 -3002.56 6.00 -92.27G -0.24 -6.00 5975361.12 616009.66 N 70.34146404 W 149.058519 S-213A OSd Tgt 4 10106.07 88.75 178. 50 5150.00 5211.90 5789.94 6498.15 -5148.22 -3002.42 6.00 -92.90G -0.24 -6.00 5975355.05 616009.90. N 70.34144746 W 149.05851824 10200.00 88.47 172.87 5152.28 5214.18 5877.65 6592.05 -5241.82 -2995.36 6.00 -92.77G -0.30 -5.99 5975261.59 616018:45 N 70.34119177 \f'J 149.05846063 End Cry 10234.45 88.37 170.80 5153.23 5215.13 5908. 93 6626.49 -5275.90 -2990.47 6.00 O.OOG -0.29 -6.00 5975227.58 616023.88 N 70.34109865 W 149.05842084 Cry 6/100 10640.46 88.37 170.80 5164.76 5226.66 6274.52 7032.34 -5676.54 -2925.61 0.00 -85.94G 0.00 0.00 5974828.07 616095.08 N 70.34000423 W 149.05789329 10700.00 88.63 167.24 5166.32 5228.22 6327.30 7091.85 -5734.95 -2914.28 6.00 -85.85G 0.43 -5.99 5974769.84 616107.34 N 70.33984465 W 149.05780115 10800.00 89.07 161.25 5168.33 5230.23 6411.78 7191.83 -5831.13 -2887.15 6.00 -85.72G 0.44 -5.98 5974674.11 616135.99 N 70.33958192 W 149.05758072 10900.00 89.52 155.27 5169.56 5231.46 6490.24 7291.82 -5923.97 -2850.13 6.00 -85.65G 0.45 -5.98 5974581.88 616174.47 N 70.33932833 W 149.05728010 11000.00 89.98 149.29 5170.00 5231.90 6561.82 7391.82 -6012.46 -2803.64 6.00 -85.63G 0.46 -5.98 5974494.15 .616222.36 N 70.33908665 W 149.05690260 S-213A OSc 1;gt 5 11004.83 90.00 149.00 5170.00 5231.90 6565.09 7396.60 -6016.60 -2801.16 6.00 -85.99G 0.46 -5.98 5974490.05 616224.90 N 70.33907534 W 149.05688251 11100.00 90.40 143.30 5169.67 5231.57 6625.74 7491.77 -6095.61 -2748.17 6.00 -86.01G 0.42 -5.99 5974411.90 616279.13 N 70.33885954 W 149.05645235 .- WellDesign Ver 3.1RT-SP3.03-HF5.00 Sld( d031rt-546) S-213\S-213\Plan S-213A OSd\S-213A (P4) OSd Generated 10/1/20042:10 PM Page 2 of 3 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Eastlng Latitude Longnude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (deg/100 It) (deg) (deg1100 It) (deg/100 It) (ltUS) (ltUS) 11200.00 90.81 137.32 5168.61 5230.51 6681.30 7591.76 -6172.52 -2684.34 6.00 -86.07G 0.41 -5.99 5974336.01 616344.17 N 70.33864949 W 149.05593424 End Cry 11201.96 9ü.82 137.20 5168.58 5230.48 6682.30 7593.72 -6173.96 -2683.02 6.00 O.OOG 0.41 -5.99 5974334.60 616345.52 N 70.33864557 W 149.05592347 TD /4-1/2" Ln, 12149.14 ./ 9ü.82 137.20 5155.00 5216.90 7165.27 8540.80 -6868.87 -2039.53 0.00 O.OOG 0.00 0.00 5973650.05 616999.90 N 70.33674768 W 149.05070112 Leqal Description: Surface: 4346 FSL 4500 FEL S35 T12N R12E UM Tie-In: 4346 FSL 4500 FEL S35 T12N R12E UM S-213A Csg Tgt: 2583 FSL 1581 FEL S34 T12N R12E UM S-213A OBd Tgt 1: 2321 FSL 1796 FEL S34 T12N R12E UM S-213A OBd Tgt 2: 1365 FSL 2077 FEL 534 T12N R12E UM S-213A OBd Tgt 3: 566 FSL 2146 FEL S34 T12N R12E UM S-213A OBd Tgt 4: 4477 FSL 2229 FEL 53 T11 N R12E UM S-213A OBd Tgt 5: 3608 FSL 2029 FEL S3 T11 N R12E UM TD / BHL: 2757 FSL 1269 FEL S3 T11 N R12E UM Northin¡:¡ (Y) [ftUS] 5980549.84 5980549.89 5978750.05 5978485.05 5977525.05 5976725.05 5975355.05 5974490.05 5973650.05 WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Eastinq (X) [ftUS] 618929.96 618929.86 616599.90 616389.90 616124.90 616069.90 616009.90 616224.90 616999.90 . . S-213IS-213IPlan S-213A OBdIS-213A (P4) OBd Generated 10/1/20042:10 PM Page 3 of 3 . Prudhoe Bay PB S Pad S-213 Plan S-213A OBd Field: Site: Well: Wellpath: --294 ·200 ·100 . S-44~S~LIPB S-42~~!!$-42PB 10 o Centre Separation [100ft/in Centre 180 h.. vs Tmvelling Cylinder Azimuth (TFO+AZI) [deg) 27C -0 100 200 --294 . . Schlumberger Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 2870.00 to 12149.14 ft Scan Method: Trav Cylinder North Maximum Radius: 10000.00 ft Error Suñace: Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/1/2004 Validated: No Version: 7 Planned From To Survey Toolcode Tool Name ft ft 155.50 2856.62 Survey #3 MWD+IFR+AK (155.50-6463.17) ~D+IFR:AK MWD + IFR [Alaska] 2856.62 4000.00 Planned: Plan #4 V1 MWD MWD - Standard 2856.62 12149.14 Planned: Plan #4 V1 MWD+IFR+MS MWD + IFR + Multi 8tation Casing Points 2870.00 2838.75 9.625 12.250 95/8" 6591.24 5226.90 7.000 8.750 7" 12149.14 5216.90 4.500 6.125 41/2" Summary Reference Offset Ctr-Ctr . . . No-Go Allowable MD MD Dista.nce. . Area Deviation Warniny ft ft ft ft ft PB S Pad Plan S-111 Plan S-111 V5 Plan: PI 2877.85 5250.00 3744.50 49.04 3695.46 Pass: Major Risk PB 8 Pad Plan S-203 Plan S-203 (East) V3 P 2881.16 3500.00 1771.79 50.71 1721.08 Pass: Major Risk PB S Pad Plan S-203 Plan S-203 (West) V5 P 2885.78 3000.00 1187.65 47.84 1139.81 Pass: Major Risk PB S Pad Plan S-208 Plan S-208 VO Plan: S- 2870.00 4900.00 3504.21 65.80 3438.42 Pass: Major Risk PB S Pad Plan 8-400 S-400 VO Plan: S-400 w 5429.03 5484.70 1009.70 71.70 938.01 Pass: Major Risk PB S Pad Plan S-401 S-401 VO Plan: S-401 w 4323.71 4978.43 1567.05 104.95 1462.09 Pass: Major Risk PB 8 Pad 8-01A S-01A V1 4757.90 4850.00 434.56 107.83 326.73 Pass: Major Risk PB 8 Pad S-01B S-01 B V1 4755.10 4850.00 431.88 107.81 324.07 Pass: Major Risk PB 8 Pad S-01 S-01 V1 4389.20 4450.00 429.06 78.84 350.22 Pass: Major Risk PB S Pad 8-02APB1 S-02APB1 V1 2919.72 2850.00 670.03 42.42 627.61 Pass: Major Risk PB S Pad 8-02A S-02A V1 2919.72 2850.00 670.03 42.42 627.61 Pass: Major Risk PB S Pad 8-02 S-02 V1 2918.54 2850.00 670.03 42.39 627.64 Pass: Major Risk PB S Pad 8-03 S-03 V1 3305.22 3450.00 216.58 51.14 165.44 Pass: Major Risk PB S Pad S-04 S-04 V1 2871.00 2900.00 760.33 40.84 719.49 Pass: Major Risk PB S Pad S-05APB1 S-05APB1 V1 2883.81 2950.00 860.06 45.31 814.75 Pass: Major Risk PB S Pad S-05A 8-05A V1 2883.81 2950.00 860.06 45.31 814.75 Pass: Major Risk PB S Pad S-05 S-05 V1 2878.78 2950.00 859.37 45.19 814.18 Pass: Major Risk PB 8 Pad S-06 S-06 V1 2890.12 3000.00 940.33 41.69 898.63 Pass: Major Risk PB 8 Pad S-07A 8-07A V1 2900.07 3200.00 1663.22 61.76 1601.45 Pass: Major Risk PB 8 Pad S-07 S-07 V1 2900.07 3200.00 1663.22 61.76 1601.45 Pass: Major Risk PB S Pad S-08 8-08 V1 2888.75 3100.03 1136.65 44.29 1092.36 Pass: Major Risk PB S Pad S-08 8-0BA V2 2888.75 3100.03 1136.65 44.29 1092.36 Pass: Major Risk PB S Pad 8-08 S-08B V3 2888.75 3100.03 1136.65 44.29 1092.36 Pass: Major Risk PB S Pad 8-09 S-09 V1 2895.57 3150.00 1251.18 45.20 1205.98 Pass: Major Risk PB S Pad 8-100 S-100 V10 2912.46 3450.00 1762.32 49.87 1712.45 Pass: Major Risk PB S Pad S-101 S-101 V3 2938.56 2850.00 760.17 42.65 717.52 Pass: Major Risk PB S Pad S-101 8-101PB1 V9 2938.56 2850.00 760.17 42.79 717.38 Pass: Major Risk PB S Pad S-102 S-102V11 2881.77 3900.00 1933.31 48.17 1885.15 Pass: Major Risk PB S Pad S-102 8-102L 1 V5 2881.77 3900.00 1933.31 48.14 1885.17 Pass: Major Risk PB S Pad S-102 8-102L1PB1 V7 2881.77 3900.00 1933.31 48.10 1885.22 Pass: Major Risk PB S Pad S-102 8-102PB1 V14 2881.77 3900.00 1933.31 48.17 1885.15 Pass: Major Risk PB 8 Pad S-103 8-103 V6 2881.65 3450.00 1347.35 46.75 1300.61 Pass: Major Risk PB S Pad S-104 8-104 V1 2870.00 5400.00 3878.94 44.26 3834.68 Pass: Major Risk PB S Pad S-105 8-105 V5 2883.61 3650.00 1555.81 39.54 1516.27 Pass: Major Risk PB S Pad S-106 8-106 V2 2887.09 3600.00 2068.73 47.39 2021.34 Pass: Major Risk PB S Pad S-106 S-106PB1 V12 2887.09 3600.00 2068.73 47.40 2021.33 Pass: Major Risk PB S Pad 8-107 S-107 V36 2878.56 3900.00 2301.09 46.30 2254.79 Pass: Major Risk PB S Pad 8-108 S-108 V6 2880.80 3050.00 421.07 34.55 386.53 Pass: Major Risk PB 8 Pad S-109 S-109 V8 2870.00 3850.00 1668.21 38.44 1629.78 Pass: Major Risk PB S Pad 8-109 S-109PB1 V2 2870.00 3850.00 1668.21 38.44 1629.78 Pass: Major Risk PB S Pad 8-10APB1 8-10APB1 V1 2872.76 3199.96 1348.18 48.50 1299.68 Pass: Major Risk ",-',,~.~... ~'". =~""--~"",,,_.-,~".~.~"..<.,..~- Company: Field: Reference Site: Reference Well: Reference Wellpath: Summary BP Amoco Prudhoe Bay PB S Pad S-213 Plan 8-213A OBd . . Schlumberger Anticollision Report PB S Pad S-10A S-10A V1 2873.72 3200.00 1347.74 48.40 1299.34 Pass: Major Risk PB S Pad 8-10 S-10 V1 2872.76 3.199.96 1348.18 48.50 1299.68 Pass: Major Risk PB S Pad S-110 S-110 V18 2870.00 6550.00 4651.88 39.67 4612.21 Pass: Major Risk PB 8 Pad S-112 8-112 V20 2893.00 3150.00 582.00 36.48 545.52 Pass: Major Risk PB S Pad S-113 S-113 V14 2893.56 3150.00 1528.06 .45.75 1482.31 Pass: Major Risk PB S Pad 8-113 S-113A V3 2893.56 3150.00 1528.06 45.60 1482.46 Pass: Major Risk PB S Pad S-113 S-113BV6 2893.56 3150.00 1528.06 45.60 1482.46 Pass: Major Risk PB 8 Pad S-114 S-114 V13 2892.01 3300.00 1745.06 47.40 1697.66 Pass: Major Risk PB S Pad S-114 S-114A V6 2892.01 3300.00 1745.06 47.25 1697.81 Pass: Major Risk PB 8 Pad S-115 S-115 ST V1 Plan: Plan 2922.45 2900.00 811.20 41.17 770.03 Pass: Major Risk PB 8 Pad 8-115 S-115V7 2922.50 2900.00 811.15 41.07 770.08 Pass: Major Risk PB 8 Pad S-116 S-116V6 2916.24 2800.00 782.12 39.78 742.35 Pass: Major Risk PB S Pad S-117 S-117V4 2926.49 2850.00 492.13 41.03 451.09 Pass: Major Risk PB S Pad 8-118 S-118V5 4237.72 4150.00 394.20 67.71 326.49 Pass: Major Risk PB S Pad S-119 Plan 8-119A V1 Plan: P 2873.02 4400.00 2971.07 58.88 2912.19 Pass: Major Risk PB S Pad S-119 S-119 V3 Plan: Plan #4 2873.02 4400.00 2971.07 48.53 2922.54 Pass: Major Risk PB 8 Pad S-11 S-11 V4 2886.40 3250.00 1413.56 45.69 1367.87 Pass: Major Risk PB S Pad S-11 S-11A V1 2886.89 3250.00 1413.87 45.70 1368.17 Pass: Major Risk PB S Pad S-11 S-11BV1 2887.16 3250.00 1414.05 45.70 1368.34 Pass: Major Risk PB S Pad S-120 S-120 V4 2942.39 3000.00 1217.48 43.83 1173.65 Pass: Major Risk PB S Pad 8-123 S-123 V10 2876.04 3150.00 1457.13 40.64 1416.49 Pass: Major Risk PB S Pad 8-12A S-12A V1 2879.26 3300.00 1609.60 41.35 1568.25 Pass: Major Risk PB S Pad 8-12 8-12 V1 2876.24 3350.00 1673.36 43.57 1629.79 Pass: Major Risk PB S Pad S-13 S-13 V1 2883.15 3350.00 1748.65 46.55 1702.10 Pass: Major Risk PB S Pad S-14 Drilling091604 S-14A V 2887.48 3450.00 1872.72 84.94 1787.78 Pass: Major Risk PB S Pad S-14 8-14 V5 2887.48 3450.00 1872.72 84.94 1787.78 Pass: Major Risk PB S Pad S-15 S-15 V2 3609.09 3600.04 761.47 63.88 697.59 Pass: Major Risk PB S Pad S-16 S-16 V1 3786.80 3750.00 865.48 81.27 784.21 Pass: Major Risk PB S Pad 8-17 S-17 V1 5602.59 5399.98 924.89 154.16 770.73 Pass: Major Risk PB S Pad S-17 S-17A V1 5602.59 5399.98 924.89 154.16 770.73 Pass: Major Risk PB S Pad S-17 S-17AL 1 V1 5602.59 5399.98 924.89 154.16 770.73 Pass: Major Risk PB S Pad S-17 S-17APB1 V1 5602.59 5399.98 924.89 154.16 770.73 Pass: Major Risk PB S Pad S-17 S-17B V1 5602.59 5399.98 924.89 154.16 770.73 Pass: Major Risk PB S Pad S-17 S-17C V1 5602.59 5399.98 924.89 154.05 770.84 Pass: Major Risk PB S Pad 8-17 S-17CPB1 V2 5602.59 5399.98 924.89 154.05 770.84 Pass: Major Risk PB S Pad S-17 S-17CPB2 V1 5602.59 5399.98 924.89 154.05 770.84 Pass: Major Risk PB S Pad S-18 S-18 V1 2912.30 2650.00 2187.88 61.21 2126.67 Pass: Major Risk PB S Pad S-18 S-18A V16 2921.24 2650.00 2189.46 61.44 2128.02 Pass: Major Risk PB S Pad 8-19 8-19 V1 3107.07 3050.00 609.87 49.07 560.80 Pass: Major Risk PB S Pad 8-200PB 1 8-200PB1 V4 2877.44 2950.00 297.53 43.84 253.69 Pass: Major Risk PB S Pad 8-200 8-200 V2 2877.44 2950.00 297.53 43.95 253.58 Pass: Major Risk PB S Pad S-201 S-201 V2 2873.65 3700.00 1590.52 43.80 1546.72 Pass: Major Risk PB S Pad 8-201 S-201PB1 V11 2879.52 3700.00 1587.91 45.59 1542.32 Pass: Major Risk PB S Pad S-20 S-20 V4 3070.48 3050.00 734.81 53.83 680.98 Pass: Major Risk PB 8 Pad S-20 S-20A V2 3070.48 3050.00 734.81 53.83 680.98 Pass: Major Risk PB 8 Pad S-213 S-213 V9 3046.08 3050.00 4.72 40.77 -36.05 FAIL: Major Risk PB 8 Pad S-215 S-215 V9 8660.10 6930.00 1126.17 129.52 996.66 Pass: Major Risk PB S Pad 8-216 8-216 V2 2896.92 2900.00 802.63 42.17 760.46 Pass: Major Risk PB S Pad S-21 8-21 V1 3203.91 3300.00 720.37 54.95 665.42 Pass: Major Risk PB S Pad 8-22A 8-22A V1 3366.54 3350.00 596.94 57.10 539.84 Pass: Major Risk PB 8 Pad 8-22B 8-22B V2 3366.54 3350.00 596.94 57.21 539.73 Pass: Major Risk PB S Pad S-22 8-22 V1 3366.59 3350.00 596.67 57.12 539.54 Pass: Major Risk PB S Pad 8-23 S-23 V1 3246.07 3300.00 665.69 52.31 613.38 Pass: Major Risk PB S Pad 8-24 S-24 V5 2966.51 3000.00 744.00 42.81 701.19 Pass: Major Risk PB S Pad 8-24 S-24A V1 3407.65 3750.00 560.69 57.55 503.14 Pass: Major Risk PB S Pad S-24 S-24B V2 3407.65 3750.00 560.69 57.55 503.14 Pass: Major Risk PB 8 Pad S-25APB1 S-25APB1 V2 2881.08 3050.00 745.08 67.79 677 .28 Pass: Major Risk PB 8 Pad S-25A S-25A V1 2906.47 2950.00 788.38 40.40 747.98 Pass: Major Risk PB 8 Pad S-25 S-25 V1 2906.47 2950.00 788.38 40.40 747.98 Pass: Major Risk PB S Pad S-26 8-26 V1 2889.85 2950.00 833.32 38.07 795.25 Pass: Major Risk PB S Pad 8-27 8-27 V1 2876.48 2950.00 869.83 37.85 831.97 Pass: Major Risk PB 8 Pad S-27 8-27A V3 2876.48 2950.00 869.83 37.85 831.97 Pass: Major Risk PB 8 Pad S-27 S-27B V7 2875.81 2950.00 869.73 37.73 831.99 Pass: Major Risk ~_ ·...-_~·-=--..-.,,·.~,..-""'......_.,,'"'...,....___,.-.--'O....."_or."'.-"""""'~·,··~~··~..,....."'T·..._.....,.._.~...".~_____.____ . . Schlumberger Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: Summary PB S Pad S-28 S-28 V4 11869.45 2950.00 910.48 111.59 798.88 Pass: Major Risk PB S Pad S-28 S-28A V1 11869.45 2950.00 910.48 111.59 798.88 Pass: Major Risk PB S Pad S-28 S-28B V2 2870.44 2950.00 910.60 39.70 870.90 Pass: Major Risk PB S Pad S-28 S-28BPB1 V7 2870.44 2950.00 910.60 39.70 870.90 Pass: Major Risk PB S Pad S-29AL 1 S-29AL 1 V1 2896.89 3050.00 1427.98 57.34 1370.63 Pass: Major Risk PB S Pad S-29A Plan S-29AL2 VO Plan: 2900.27 3050.00 1429.74 57.24 1372.50 Pass: Major Risk PB S Pad S-29A S-29A V1 2896.89 3050.00 1427.98 57.34 1370.63 Pass: Major Risk PB S Pad S-29 Plan S-29B V1 Plan: S- 2900.27 3050.00 1429.74 57.34 1372.40 Pass: Major Risk PB S Pad S-29 S-29 V1 2896.89 3050.00 1427.98 57.34 1370.63 Pass: Major Risk PB S Pad S-30 S-30 V1 2900.00 3050.00 1016.14 38.62 977.52 Pass: Major Risk PB S Pad S-31A S-31A V3 3224.79 3700.00 755.81 64.61 691.20 Pass: Major Risk PB S Pad S-31 S-31 V1 3224.79 3700.00 755.81 64.61 691.20 Pass: Major Risk PB S Pad S-32 S-32 V1 2889.28 3200.00 1300.39 45.96 1254.43 Pass: Major Risk PB S Pad S-33 S-33 V1 2900.00 3100.00 1162.82 39.24 1123.58 Pass: Major Risk PB S Pad S-34 S-34 V1 2879.25 3200.00 1439.74 36.64 1403.10 Pass: Major Risk PB S Pad S-35 S-35 V1 2874.27 3550.00 1411.58 56.50 1355.08 Pass: Major Risk PB S Pad S-36 S-36 V1 2876.35 3300.00 1489.80 38.52 1451.28 Pass: Major Risk PB S Pad S-37 S-37 V1 2880.94 3350.00 1567.21 39.45 1527.76 Pass: Major Risk PB S Pad S-38 S-38 V1 2876.14 3150.00 1268.58 36.10 1232.48 Pass: Major Risk PB S Pad S-40A S-40A V1 2881.03 2600.00 1334.40 39.59 1294.81 Pass: Major Risk PB S Pad S-40 S-40 V1 2881.03 2600.00 1334.40 39.59 1294.81 Pass: Major Risk PB S Pad S-41L1 S-41L1 V1 2870.00 4700.00 2432.65 43.68 2388.97 Pass: Major Risk PB S Pad S-41PB1 S-41PB1 V1 2870.00 4700.00 2432.65 43.68 2388.97 Pass: Major Risk PB S Pad S-41 S-41 V1 2870.00 4700.00 2432.65 43.68 2388.97 Pass: Major Risk PB S Pad S-42PB1 S-42PB1 V1 2870.82 2900.00 172.49 34.98 137.50 Pass: Major Risk PB S Pad S-42 S-42 V2 2870.82 2900.00 172.49 34.98 137.50 Pass: Major Risk PB S Pad S-43L 1 S-43L 1 V2 2870.79 3150.00 647.04 38.61 608.42 Pass: Major Risk PB S Pad S-43 S-43 V3 2870.79 3150.00 647.03 38.50 608.53 Pass: Major Risk PB S Pad S-44L 1 PB 1 S-44L1PB1 V3 2896.64 2950.00 199.72 35.01 164.72 Pass: Major Risk PB S Pad S-44L 1 S-44L 1 V5 2896.64 2950.00 199.72 35.01 164.71 Pass: Major Risk PB S Pad S-44 S-44 V10 2896.64 2950.00 199.72 35.01 164.71 Pass: Major Risk ---_..:;.,.....-....._--...,.."..,..--~.~ SONDRA D STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 113 "Mastercard Check" DATE if) PAY TO THE /'0""· /'" /I Ii I $ H ORDER OF /"-'\.. . ~ L~I....-,· ~ C)-f1€.. ~V\'d.Ì'""·M. (lX"l}'~\+~"--' DOLLARS First National Bank Alaska Anchorage, AK 99501 . .... . .' ..... .../.... / _'~/ MEM~r ß\..Ã.~-Z '3A \L\\L'Z ~5 \1.,_~l/,..··· '-'··~':~>;\,.,'t~I~~5:~ ~- ...",.-__.....:;:;;.r; I: ~ 25 2000bOI:Qq ~l...lb 2 2 711' ~ Sbl.lI· 0 ~ ~] . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~Æ?f ~c--- 2/3/l PTD# ..20;7'- 2),,-~¡q X Development Service CHECK WßA T APPLJES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn. Tbe permit is for a Dew w eJl bore segment of existing well,. . Permit No, .. API No. Production.sbould continue to be reported as a function' of tbe original API Dumber. stated above. HOLE In accordance witb' 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be dearly differentiated "iD botb name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for we)) (name on permit). Pll.,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved su bj ect ·to fuD compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing eneption. (CompaDY Name) assumes tbe liability of any protest to the spacing .e~ception tbat may occur. AU dry ditch sample sets submitted to the Commission must be in DO greater than 30' sample iD1erva1s from below tbe permafrost or from wbere samples are fint caught and ] 0' sample inter-vals through target zones. Field & Pool PRUDHOE BAY, POLARIS OIL - 640160 Well Name: PRUDHOE BAY UN POL S-213A Program DEV Well bore seg ~ PTD#: 2042130 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal D Administration 1 p~(lT)iUee attached ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Y~$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2Leas~ ~number ~appropriate ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Ye$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 ~U~nique weltn~a[l1~~aod oumb_er ~ ~ ~ ~ ~ ~ . . . . . _ . . . . . . . . . . . . . . . . . . . . . . _ _ . . Y~$ . _ . . . . . . . _ . . . . . . . _ . . . . . . . . . . . . . . . . _ . . . . . . . . . . _ . . . . . . . . ~ . . . . . . . . _ . . . . . . . . . . . 4 WeUJQcat~d in.a~d_efinedppol _ ~ ~ ~ ~ ~ . . . . . . _ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ . Y~$ ~ ~ ~ ~ ~ . . ~ _ ~ ~ ~ ~ . . . _ _ ~ ~ ~ ~ . ~ . . . ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ . 5 WeJUQcaled pr.operdistance from driJling unilbound~ary. . . _ ~ ~ ~ ~ ~ ~ . . Y~$ CO 484,.RULEQNE SEt ¡:>OLARIS POOL SP,A.CING.REQUIßEMENtSAT 20 ACRES PER WELL ,A.F\lD 6 WeJUQcat~dproperdistance_fromQtberwelJs.. - - ~ ~ ~ ~ ~ ~ ~..... _ ~ ~ ~ ~ ~ ~. ~ ~.. _ ~ Y~$ ~,A.50Q·SET6,A.C~fROMTHEPQQLBQUNDRYS,THEREARE50TtlERPOLARISPOO.LWELLSWITI:f. ~_ 7SutficienLacrea~e_aYailable indJilliog unjt ~ ~ ~ ~ ~ . . . . . _ _ _ ~ ~ ~ ~ ~ . . ~ ~ . ~ Y~$ INtHE.SE 1/4 OFSECTtQN34t12F\1,.R12E AND~QNE OTHER I='OLARJS POOL WELL IN THE I'JE j£4, ~ 8 Jfd~viated, js. weJlbQre platincJuded ~ ~ . . ~ ~ ~ . . ~ ~ ~ ~ ~ ~ ~ ~ ~ . .. ~ ~ ~ . ~ ~ Ye$ ~ ~ ~ . . . SEC.3J~.1 1 F\I R:12E. THE ~C.LOSEST POINTIF\I TtlE WELL TOtHEPQQL BQUNDRY IS~9,9.o0\ _ ~ ~ ~ ~ ~ _ 9 Operator OI1I~ affected party ~ ~ ~ ~ ~ ~ ~ _ _ _ ~ ~ ~ ~ ~ . ~ ~ . . . . ~ _ ~ ~ ~ ~ ~ ~ . . _ ~ ~ ~ ~ ~ ~ ~ Y ~$ ~ ~ ~ ~ ~ . ~ . ~ ~ ~ ~ . . . . ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ . _ ~ ~ ~ . . . . . _ ~ ~ ~ ~ ~ ~ . _ ~ ~ ~ ~ ~ ~ ~ . . _ 10 .Operator bas.appr9priate.b.ond inJQrce . . . . . _ . . . . . . . . . . . . . _ . . . . . . . . _ _ ~ . . Y~s . _ _ . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . ~ . . . . . . . . . _ . . . . . . _ . . . 11 P~rrTJit C.an be iS$u.ed wjtbQut con$erva.tion Qrder ~ ~ . ~ . . _ _ ~ ~ ~ ~ . . . . _ ~ ~ ~ ~ . ~ . Ye$ ~ ~ ~ . . . . . ~ ~ ~ ~ ~ . . . ~ ~ ~ . . ~ ~ ~ ~ ~ ~ . _ ~ ~ ~ . . . . . _ ~ ~ ~ ~ ~ . . _ ~ ~ ~ ~ ~ ~ ~ . . ~ Appr Date 12 P~rrTJitc.ao be issu.ed wjtbQut ad.rTJinistratilleappr9vaJ . . . . ~ _ ~ ~ . . . . . _ ~ ~ ~ ~ ~ ~ . ~ _ Y~s ~ ~ ~ ~ ~ . . _ _ ~ ~ ~ ~ ~ ~ . . _ ~ _ ~ ~ ~ ~ . . . _ ~ ~ ~ ~ ~ ~ . . _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . RPC 10/26/2004 13 Can permit be approved before 15-daywait Yes 14 WellJQcated within area al1d~strataauthorized byJojecti9o Ord~r # (putlO# in.c9[11[11~otS) (FQr. .NA ~ ~ ~ . . . . ~ ~ ~ ~ . . . . _ _ ~ ~ ~ ~ . . _ ~ ~ ~ ~ ~ . . ~ ~ . . _ ~ ~ ~ ~ . . . _ ~ _ ~ ~ ~ ~ ~ . . . _ ~ ~ ~ ~ . 15 .AJI welJs_withinJI4.llJite.area.of reyiew id~otified (F9r ~ervjq:!we[l Only). . . . ~ . . . . . . . . . . .NA . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . 16 PJe-produ.ced iojector; duratiORof pre-production tess. than:3 mOl1tbs (For service welt QnJy) ~ ~ NA _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ . . ~ ~ ~ ~ ~ . ~ . ~ _ ~ ~ . ~ _ . . ~ ~ ~ ~ ~ ~ . ~ _ _ _ ~ ~ . ~ . . _ _ ~ ~ ~ ~ ~ . .. ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ . . 17 AÇMP~ F:il1djngof CQn,Si,Steocy.h.as beenj~sued. fpr.tbi$ project ~ ~ . . . . . _ ~ ~ ~ ~ . . ~ NA ~ ~ ~ ~ ~ _ _ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ . . . _ ~ ~ ~ ~ ~ . ~ . _ ~ ~ ~ ~ ~ ~ ~ . . Engineering Appr WGA 18 19 20 21 22 23 24 25 26 27 Date 28 10/26/2004 29 30 31 32 33 34 Geology 35 36 Date 37 10/26/2004 38 39 Appr RPC Geologic Commissioner: ØTj . .C90du.ctor ~tril1gpJQvided ~ . ~ . . _ . ~ ~ ~ ~ . . . . . . . _ _ ~ ~ ~ ~ ~ ~ ~ . _ ~NA _ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ . _ ~ ~ ~ ~ ~ . . . ~ _ ~ ~ ~ ~ ~ . _ .S.uúac~cas.ingpJQtec.ts. alLknown USDWs ~ _ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ . _ . ~ ~ ~ ~ ~ ~ .. ~ ~NA ~ ~ ~ . . . . . ~ ~ ~ . . . . _ ~ ~ ~ ~ . . . ~ ~ ~ . . . _ ~ _ ~ ~ ~ ~ ~ ~ . . ~ ~ ~ ~ ~ . . . ~ .CMT vol. adeQu.ate.to circ.utateoÐconductpr. & SUJf.C$g ~ ~ ~ ~ . ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ . ~ . _ ~ ~ ~ ~ NA . _ _ ~ ~ ~ ~ . . _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . . ~ ~ ~ ~ ~ ~ . .. ~ ~ ~ . ~ . . . _ ~ ~ ~ . . ~ . . . _ .CMT v_ot adeQu.ate.to tie-inlQng .string tosuú çs.g. . _ _ . _ _ _ ~ ~ ~ ~ ~ ~ ~ ~ . ~ _ No~ ~ ~ ~ ~ ~ ~ . _ ~ ~ ~ ~ ~ . . . _ . ~ ~ ~ . ~ _ ~ _ ~ ~ ~ ~ . . . _ _ _ ~ ~ ~ ~ . . _ ~ . ~ . _ _ ~ ~ ~ ~ . . CMT will coYer~all knowÐ.productiye bQri~Qn.s_ ~ _ ~ ~ ~ ~ ~ ~ ~ . . ~ _ ~ ~ ~ ~ ~ ~ . _ _ ~ ~ ~ ~ ~ . No. _ . ~ ~ ~ ~ ~ Slotted, ~ ~ . . . ~ _ ~ ~ ~ . ~ . _ . ~ ~ ~ ~ . ~ ~ . ~ ~ ~ ~ . . . . . ~ ~ ~ ~ . . . C~asiog de~sigo~ adeQua~te f9r C,.T" B .&. perroafr9$t _ _ _ ~ ~ ~ ~ ~ _ . . ~ ~ ~ . . Y~$ ~ ~ ~ . . ~ ~ _ ~ ~ ~ ~ . _ . ~ ~ ~ ~ . . . ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ . . . . ~ ~ ~ ~ ~ ~ ~ . _ ~ ~ ~ ~ ~ . . _ _ _Adequate tankage. OJ re.serve pit ~ . . . . _ ~ ~ ~ ~ ~ . _ ~ ~ ~ . ~ ~ . _ . ~ ~ ~ ~ Y~$ . . _ ~ ~ DQY90 16. ~ . ~ . . _ ~ ~ ~ ~ ~ ~. ~ ~ . ~ . . . . ~ ~ ~ . . . _ ~ ~ ~ ~ ~ . . . _ ~ ~ ~ ~ ~ ~ . _ ~ . ~ ~ ~ . . _ Jfa.re-drilt basa 10-403 fQr abandQnrTJe~nt be~o apPJQved ~ ~ ~ ~ ~ ~ ~ . . . _ _ ~ Y~s ~ 10/14/2004. ~ ~ ~ . . . . ~ ~ ~ ~ . ~ . ~ ~ ~ ~ ~ . . . _ . _ ~ ~ ~ ~ ~ . . . ~ ~ ~ ~ ~ ~ ~ . . _ ~ ~ ~ ~ ~ ~ . ~ . ~ ~ ~ ~ . ~ _ _Adequate.we[lbore~eparatioÐ.propo~ed. . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~$. . . . . . . . . . . . . . . . . . _ . . . . . . . ~ . . . . . . . _ . . . . . . . . . ~ ~ . . . . . . . . . . . . . . . . . . . _ . _ . . . . . . . Jtdjverter Jeq_uiJed, does it meet reguJations~ . ~ ~ ~ ~ . ~ . . . . . _ _ ~ ~ ~ ~ ~ . . _ ~ ~ ~ ~ ~ . . . NA ~ ~ ~ ~ . . . Sidetrack.. . _ ~ ~ ~ . ~ . . _ ~ ~ ~ . . . _ _ ~ ~ ~ ~ ~ . . _ DJiUiog fluid.prograrTJ sc.hematic& eCLuipJistadequat~~ . ~ . . ~ _ . _ ~ ~ ~ ~ ~ ~ . _ ~ . Y~$ ~ ~ ~ ~ . ~ . Max MW.9,3. ppg, ~ ~ ~ ~ ~ ~ _ _ _ _ ~ ~ ~ . ~ . ~ . _ _ ~ ~ . . . . _ ~ ~ ~ ~ ~ ~ . . .BOPEs, d9they meet reguJa.tion ~ _ ~ ~ ~ ~ ~ ~ ~ . . . _ _ ~ ~ ~ ~ . . _ _ _ _ ~ ~ Y~e$ . . . _ ~ ~ ~ ~ ~ . . . ~ ~ ~ ~ ~ . . _ ~ ~ ~ ~ . . _ _ ~ ~ ~ . ~ . . _ ~ _ ~ ~ ~ ~ ~ . . . _ ~ ~ ~ ~ . . . _ _ ~ ~ ~ ~ ~ . . BOPEpres:;;ra.tiog appropriate; testto.(pu.t p~ig iÐcomment$). . _ ~ ~ ~ ~ ~ ~ . Y~$ ~ Test t93500. psi.MSp 18.07 psi. _ ~ ~ ~ ~ ~ ~ ~ . . ~ . ~ ~ ~ . . . . . _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . ~ _ ~C~hoke~llJanjfold cQrTJpJies. w/APtRP-53lMay 84) _ _ _ ~ ~ ~ ~ ~ ~ . . . . ~ _ ~ ~ ~ ~ ~ . _ Y~$ ~ ~ ~ ~ ~ ~ .. ~ ~ ~ ~ . . _ . ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ . . . ~ ~ ~ ~ ~ . . . _ ~ ~ ~ ~ ~ ~ . . . _ _ ~ ~ . . . ~ WQrk will occ_ur withoutoperatjon .shutdown ~ ~ ~ ~ . . . _ ~ ~ . . . _ Y~s ~ ~ ~ . . . _ ~ ~ ~ . ~ ~ . _ ~ ~ ~ ~ . . _ ~ ~ ~ . . _ _ ~ ~ ~ ~ . _ . _ ~ ~ ~ . ~ . . ~ ~ ~ . . ~ _ ~ ~ ~ ~ . _ ~ Js. pres.ence_ Qf H2S gas~ prob.able. ~ _ _ _ ~ ~ ~ ~ ~ ~ . . . ~ _ _ ~ ~ ~ . ~ . . . ~ No ~ ~ ~ . . . _ . F\lQtan H2S pad. ~ . _ ~ ~ ~ ~ . ~ . . . ~ ~ ~ ~ ~ ~. _ ~ ~ ~ ~ ~ . . . _ _ ~ ~ ~ . ~ ~ Meçba~nicaLcoodjHon 9fwells within ,A.Oß yerified (For~s~ervice welJ onM ~ ~ ~ . . _ _ _ ~ ~ ~ ~ ~ ~ NA . ~ ~ ~ ~ ~ ~ . ~ . ~ ~ ~ ~ . . _ . ~ ~ ~ ~ ~ . . . ~ ~ ~ . . _ _ ~ ~ ~ ~ . . . _ _ . ~ ~ ~ ~ . . . . _ ~ ~ ~ ~ ~ . . ~ _ ~ ~ ~ ~ ~ . . _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . p~(IT)it c~an be issu.ed wfo hydrogen. s.utfide meas~ures ~ ~ ~ ~ ~ ~ . . _ . . ~ ~ . . . . _ _ ~ ~ ~ ~ ~ ~ Y~s ~ ~ ~ ~ ~ ~ ~ ~ . . . _ _ ~ ~ ~ . . _ ~ ~ ~ . ~ ~ ~ _ ~ ~ ~ . . . . . _ ~ ~ . ~ . ~ ~ . . . ~ ~ ~ . ~ . . . _ ~ ~D.ata.PJeseoted Qn~ potential oveJpres.sure ~zOl1es ~ ~ . . . . _ _ ~ ~ ~ ~ ~ ~ ~ ~ _ _ ~ ~ ~ ~ . ~ . . . . NA ~ ~ . . . . _ ~ ~ ~ . . . ~ ~ ~ ~ . ~ . _ _ S~ismicanalysjs. Qf shaJlow gasz90es~ ~ ~ ~ ~ ~ _ _ ~ ~ ~ . . . . _ . ~ . ~NA . _ _ _ ~ ~ . . . _ ~ ~ ~ ~ . . . . ~ ~ ~ ~ ~ . _ ~ ~ ~ ~ ~ . _ . _ ~ ~ ~ ~ ~ . . . . ~ ~ ~ ~ ~ ~ . . . . _ .S~abedcOl1ditioo $u.rvey .(if off-~h.ore) _ ~ ~ ~ . . ~ . . . . _ ~ ~ ~ ~ ~ ~ ~ .. _ _ ~ ~ ~ . . . ~ . _ ~NA ~ ~ . . . ~ ~ ~ ~ ~ . ~ . _ _ ~ . . . . ~ ~ CQnta~ct l1amelphOl1eJorweekly progre~s.reports [e¡cploratory .only] ~ ~ ~ ~ . . _ . ~ ~ ~ ~ ~ ~ ~ . NA ~ ~ ~ . ~ ~ . . _ ~ ~ ~ . ~ . . ~ ~ ~ . . . . . _ ~ ~ ~ ~ . ~ ~ ~ ~ ~ . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - ~ - - - - - - - - ~ - - - - - ~ Date: Engineering Commissioner: ~ 'iJd0œ, Yzf/"jC Date Date Jo/~?l1- . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I I I I I I I I I I I I I I I I I I I Date: 4/11/2005 Schlumberger Fluid Analysis on Bottomhole Samples BP Field: Prudhoe Bay Well: S-213A CONFIDENTIAL Black Oil Full PVT Study Report Prepared for Greg Bernaski BP CONFIDENTIAL Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F Prepared by: Meisong Yan Reviewed by: Dennis D'Cruz Schlumberger WCP Oilphase-DBR 16223 Park Row, Suite 170 Houston, Texas, 77084 (281) 829-2225 Report #200400350 I I Client: Well: Installation: Field: Sand: Job #: Prudhoe Bay BP S-213A 200400350 I Table of Contents Schlumbep88P List of Figures . List of Tables .........." . I EXECUTIVE SUMMARY. Objective Introduction Scope of Work.. Results Sequence of Events. . Chain of Sample. Custody.. ............... I . .................... ........ .......... ................... I RESULTS AND..DlSCUSSIONS.. . Fluids Preparation.an.d.Analysis.. Reservoir Fluid.Analysis.. I .............. .............., ................ .................." I PVT Analysis on Sample#:1.01; CSB.1759-.QA; .0BdSand; .MD:;:6824 ftTV.O:;: 5258 It IVOSS;::; .c5.196.ft.. Reservoir Oil Viscosity.at Tees.. ................... PVT Analysis on .S.ample#:.1.04;.CSB.7.476".MA; ORa Sand; Mo. ;:;:6117ftTVD:;:5130 ftIVOSS:;: .-5068.ft.... Reservoir Oil Viscosity.atTees... .... ......... ...... I PVT Analysis on Sample#:.1.08;.CSB. 7.755".QA; .0Bc Sand;MD .:;:6403 ftT\lO:;: 5190 It IVDSS;::;c5.128ft Reservoir Oil Viscosity.at Tres. I PVT Analysis on Sample#: .1.09;. CSB. 7.690".QA; .0Bb Sand; .MD:;: 6247 ftT\lD:;:: 5151 It IVDSS;::;c5090.ft.. . Reservoir Oil Viscosity.at Tres. . . I PVT Analysis on .S.ample#: 1.10;CSB1761-QA; .0A~LQw.er. Sand; MD;:;6059ft; NO. ;:;:5084ftTVDSS;:;: "5022:ft.. Reservoir Oil Viscosity.at Tres.. PVT Analysis on .S.ample#:.1.11;CSB.1725-QA; .Mc. Sand; MD;:;5747ft NO. ;:;:4920ft;TVDSS:;:~4858:ft.. Constant Composition Expansioo. at .Tres. . . Differential Vaporizatioo. . . Oil Phase Properties... Gas Phase Properties.. Compositions Reservoir Oil Viscosity.at Tees. . . I I ...................... I PVT Analysis on Sample#:.1.12;.CSBJ.680".QA;.Mb.1SaDd;MD:;: 5531 It IVD;::;4180ft IVDSS;:;"4718ft.. Constant Composition Expansioo. at .Ires. . . Dead Oil Viscosity. at Tees.. I I I I I WCP Oilphase-DBR ..................., . 3 4 5 5 5 5 5 7 7 8 8 8 44 44 47 47 50 50 53 53 56 56 59 59 61 61 61 61 67 70 70 72 Job #: 200400350 I I Client: Well: Installation: Field: Sand: Job #: Prudhoe Bay BP S-213A 200400350 I Appendix A: Nomenclature and Definitions . Appendix B: M.o.lecularWeightsand.D.ensities.Us.ed ... Appendix C: EQUIPMENT. Fluid Preparatioa and Validation .. . Fluid Volumetric. (PVT) .and. Viscosity. Equipment. . Appendix D: PROC.EDURE. Fluids Preparation. and. Validation... .. . .... ............ ...... ......... . Constant Composition. Expansion. Procedure Differential Vaporization.Procedure... Multi-Stage Separation JesL ... ...... ..... ..... ............ ... .. Liquid Phase Viscosity. and Density. Measurements .During DV Step. . Stock-Tank Oil.(STO). Viscosity. and. Density.Measurements... Asphaltene, Wax. and Sulfur. Content Measuremønts . . SAR(P)A Analysis... High- Temperature .Higb. Pressure. Filtration. Test. . ........................, I ..............".. I I I ... ........... I I I I I I I I I I I I WCP Oilphase-DBR 2 73 74 75 75 75 78 78 78 78 78 79 79 79 80 80 Job #: 200400350 I I Client Well: Installation: Prudhoe Bay BP S-213A Field: Sand: Job #: 200400350 I List o' Figures I Figure 1: Stock Tank .Oil.Chr.omatogr.am .(Sample .1.011.. Figure 2: k-PloUor.Equilibrium .Check (Sample. 1.01) .. Figure 3: Stock Tank .Oil.Chr.omatogr.am.(Sample1.02I.. Figure 4: k-PloUor.Equilibrium .Check .(Sample.1.02). Figure 5: Stock Tank .Oil.Chr.omatogr.am.(Sample .1.04).. . Figure 6: k-PloUor.Equilibrium .Check .(Sample.1.04).. . Figure 7: Stock Tank .Oil.Chr.omatogr.am.(Sample 1.051.. Figure 8: k-PloUor.Equilibrium .Check (Sample. 1.05) .. Figure 9: Stock Tank .Oil.Chr.omatogr.am .(Sample1.07I.. Figure 10: k-PloUor. Equilibrium.Check.(Sample.1.07J.. Figure 11: Stock Tank Oil Chromatogram .(Sampl.e.1.081.. Figure 12: k-PloUor. Equilibrium.Check.(Sample .1.08).. Figure 13: Stock Tank Oil Chromatogram .(Sampl.e.1.D91.. Figure 14: k-PloUor. Equilibrium.Check.(Sample.1.09l.. Figure 15: Stock Tank Oil Chromatogram .(Sampl.e.1.101.... Figure 16: k-PloUor. Equilibrium. Check.(Sample.1.10l.. Figure 17: Stock Tank. Oil Chromatogram {Sampl.e.1.111 Figure 18: k-PloUor. Equilibrium. Check.(Sample.1.11J.. Figure 19: Stock Tank Oil Chromatogram .(Sample.1.121.. Figure 20: k-PloUor. Equilibrium.Check.(Sample.1.12).. Figure 21: Reservoir .Fluid Vis.cosity.1.D4°F (S.ample .1.0.1). Figure 22: Reservoir .Fluid Viscosity.1.01.oF .(Sample1.041. Figure 23: Reservoir .Fluid Vis.cosity.1.03°F {Sample .1.081. Figure 24: Reservoir .Fluid Vis.cosity.1.D2°F {Sample1.091. Figure 25: Reservoir .Fluid Vis.cosity.1.01°F {Sample .1.101. Figure 26: Constant .Compnsition .Expansion .a198.0°F.c .Relative Volume... Figure 27: Differentialliberatioß.98~F".Liquid.Properties.. . Figure 28: Differentialliberatioß.98°F".Gas Properties.. Figure 29: Reservoir .Fluid Viscosity. 98°F .. Figure 30: ConstantCompnsition .Expansion .a195.0?F.c .Relative Volume... I I I I I I I I I I I I I I I WCP Oilphase-DBR 3 ................ .............................", ..... ...... ....." ................. . .................. . ............. ................ . . .. . ........... 15 15 18 18 21 21 24 24 27 27 30 30 33 33 36 36 39 39 42 42 45 48 51 54 57 60 63 65 68 71 Job #: 200400350 I I Client Well: Installation: 200400350 BP S-213A Field: Sand: Job #: Prudhoe Bay I List of Tables Table 1: Well and .Sample .Identifjcation. . . .. . .. . . . . .. . . . . . . . .. .. ................................................................. Table 2: Sampling aDd .Transfer Summary. .. . ... ... .. ... .... ... ... .. ... . .. . .. ... . .. ... . ... ..... .... .............................. Table 3: Reservoir Fluid Properties... .. ... . .. ... . ... .. ... . ... ... .. . .. ... . .. . .. ... ... ... .... ..... .................................. Table 4: Stock-Iank.Oil Properties... ..... . .. . ... ... ..... . .. . ... ... .. ... .. ......................... .............................. Table 5: C30+ CompositioD.. GOR. °API. by Zero~Flash .(Sample .1.01). Table 6: Calculated. Flujd. Properties. .. Table 7: C30+ CompositioD.. GOR. °API. by Zero~Flash .(Sample .1.02).. Table 8: Calculated. Flujd. Properties. .. Table 9: C30+ CompositioD.. GOR.. ~API. by Zero~Flash .(Sample .1.04).. Table 10: Calculated .Fluid .Properties.... Table 11: C30+ Composition..GOR..oAPI..by.Zero"Flash .(Sample.1.05).. Table 12: Calculated .Fluid Properties .. Table 13: C30+ Composition..GOR..oAPI..by.Zero"Flash (Sample. .1.07). Table 14: Calculated .Fluid .P.roperties. ...................... Table 15: C30+ Composition. .GOR..oAPJ..by.Zero"Flash .(Sample. .1.08) Table 16: Calculated .FluidProperties.. Table 17: C30+ Composition. .GOR..~APJ..by.Zero"Flash .(Sample. .1.09).. Table 18: Calculated.Fluid.Properties ............... ......... . . ........... .... ........ .... Table 19: C30+ Composition..G OR. .oAPJ.. by. Zero"Flash .(Sample. .1.10) . . Table 20: Calculated .Fluid .Properties.. Table 21: C30+ Composition. .GOR. .oAPI..by.Zero"Flash .(Sample. .1.11)... Table22:Calculated.Fluid.Properties ........ .............. ..... .............. Table 23: C30+ Composjtion. .GOR. .oAPI..by.Zero"Flash .(Sample.1.12).. Table 24: Calculated .Fluid .Properties ................. .... ........... ......... ....... Table 25: Summa'Y 01. Results .01. Sample. 1..01. .. Table 26: Reservoir.FluidViscosity.1.04°FtSampJe.1.U1).. Table 27: Summa'Y 01. Results .01. SampJe.1..04.. Table 28: Reservoir .Fluid Vis.cosity.1.01 OF .(SampJe .1.04) . Table 29: Summa'Y otResults.ofSample.1..08 ..... ............................... Table 30: Reservoir.FluidVis.cosity.103°F.(SampJe 1.08) . ............................. Table 31: SummaryotResults.ofSample.1..09. Table 32: ReservoirFluid.Viscosity.102°F .(SampJe1.09). Table 33: SummaryotResults.ofSample.1.1O ................. . Table 34: ReservoirFluid.Viscosity.1.01°F .(SampJe .1.10). Table 35: Summary 01. Results .01. Sample. '...1, Table 36: ConstantComposition .Expansion .a198.0°F .(Sample .1.1.1).. Table 37: Differential Liberation.Test98~F~.liquid.Properties.. Table 38: Differentialliberation.Test98°F~.Gas Properties.. Table 39: Differential Li beration. Test98~F~. Va por & S10 .Composition(mol %} . . . . Table 40: ReservoirFluidVis.cosity.98°F.. .. . ........ ........... Table 41: Summa'Y of Results .01. Sample. 1.12 .. Table 42: Constant .Composition .Expansion .a195.0~F .(Sample .1.12). Table 43: Dead Oil Vjscosity .95°F .(Sample 1.12) I I ...................... I . . ...... .......... I I I ...........". I I I I . ............". . . .. .. . ....................., I I I I I I WCP Oilphase-DBR 4 9 10 11 12 13 14 16 17 19 20 22 23 25 26 28 29 31 32 34 35 37 38 40 41 43 44 46 47 49 50 52 53 55 56 58 59 62 64 66 67 69 70 72 Job #: 200400350 I I Client: BP Well: S-213A Installation: Field: Sand: Job #: Prudhoe Bay ScRlolberg.. 200400350 I EXECUTIVE SUMMARY I Objective To evaluate the composition and phase behavior of the bottomhole fluid samples collected during the modular formation dynamics testing (MDT). Introduction At the request of BP, Oilphase-DBR has conducted a fluid analysis study on bottomhole fluid samples collected during the modular formation dynamics testing (MDT) of Well S-213A drilled in the field Prudhoe Bay. I I Scope of Work · Homogenize bottomhole hydrocarbon fluid samples at the reservoir conditions with rocking for five · Conduct preliminary evaluation on bottomhole hydrocarbon samples that include single-stage flash Gas-Oil Ratio (GOR). reservoir fluid composition, stock-tank oil (STO) and monophasic fluid properties. · Select representative samples for the PVT study. · Conduct a Constant Composition Expansion (CCE) test at the reservoir temperature. · Conduct differential vaporization at the reservoir temperature. · Also conduct viscosity measurements of the oil at the reservoir temperature. Results The following bullets summarize the PVT analysis conducted on the bottom hole hydrocarbon samples: · Ten bottom hole samples were used for validation purposes. They were homogenized at the reservoir conditions for five days. At the depth of 6824 feet we have two samples - 1.01 and 1.02. · The zero flash GOR was determined to be from 307 - 310 SCF/STB, and the STO density to be from 0.910 - 0.910 g/cc. Subsequently, sample 1.01 was selected for the PVT study and the following are the results: · The bubble point pressure at reservoir temperature was determined to be 2,013 psia. · The reservoir fluid viscosity of sample 1.01 was measured to be 7.4 cP at bubblepoint pressure and 8.0 cP at the initial pressure. The stock tank oil viscosity at 104°F was measured as 20.6 cP. At the depth of 6117 feet we have two samples - 1.04 and 1.05. · The zero flash GOR was determined to be from 225 - 234 SCF/STB, and the STO density to be from 0.941 - 0.942 g/cc. Subsequently, sample 1.04 was selected for the PVT study and the following are the results: · The bubble point pressure at reservoir temperature was determined to be 1,987 psia. · The reservoir fluid viscosity of sample 1.04 was measured to be 29.1 cP at bubblepoint pressure and 31.4 cP at the initial pressure. The stock tank oil viscosity at 101°F was measured as 105.1 cPo At the depth of 6000 feet we have one sample - 1.07. · The zero flash GOR was determined to be 15,670 SCF/STB, and the STO density to be 0.836 g/cc. At the depth of 6403 feet we have one sample - 1.08. · The zero flash GOR was determined to be 291 SCF/STB, and the STO density to be 0.907 g/cc. Subsequently, sample 1.08 was used for the PVT study and the following are the results: · The bubble point pressure at reservoir temperature was determined to be 1,947 psia. · The reservoir fluid viscosity of sample 1.08 was measured to be 11.0 cP at bubblepoint pressure and 11.9 cP at the initial pressure. The stock tank oil viscosity at 103°F was measured as 20.9 cP. At the depth of 6247 feet we have one sample - 1.09. · The zero flash GOR was determined to be 260 SCF/STB, and the STO density to be 0.917 g/cc. Subsequently, sample 1.09 was used for the PVT study and the following are the results: · The bubble point pressure at reservoir temperature was determined to be 1,884 psia. · The reservoir fluid viscosity of sample 1.09 was measured to be 11.6 cP at bubblepoint pressure and 12.7 cP at the initial pressure. The stock tank oil viscosity at 102°F was measured as 32.3 cP. I I I I I I I I I I I I I WCP Oilphase-DBR 5 Job #: 200400350 Client: BP Field: Well: S-213A Sand: Installation: Job #: At the depth of 6059 feet we have one sample - 1.10. · The zero flash GOR was determined to be 212 SCF/STB, and the STO density to be 0.936 glee. Subsequently, sample 1.10 was used for the PVT study and the following are the results: The bubble point pressure at reservoir temperature was determined to be 1,836 psia. The reservoir fluid viscosity of sample 1.10 was measured to be 20.4 cP at bubblepoint pressure and 26.3 cP at the initial pressure. The stock tank oil viscosity at 101°F was measured as 75.7 cPo At the depth of 5747 feet we have one sample - 1.11. · The zero flash GOR was determined to be 194 SCF/STB, and the STO density to be 0.972 glee. Subsequently, sample 1.11 was used for the PVT study and the following are the results: The bubble point pressure at reservoir temperature was determined to be 1,818 psia. The reservoir fluid viscosity of sample 1.11 was measured to be 259.8 cP at bubblepoint pressure and 294.4 cP at the initial pressure. The stock tank oil viscosity at 98°F was measured as 1277 cP. Atthe depth of 5531 feet we have one sample - 1.12. · The zero flash GOR was determined to be 203 SCF/STB, and the STO density to be 0.980 glee. Subsequently, sample 1.12 was used for the PVT study and the following are the results: The bubble point pressure at reservoir temperature was determined to be 1)69 psia. During the PVT testing on sample 1.12, we didn't have enough volume for the DV and the viscosity testing. So we blewdown the residual sample inside the cylinder and recovered about 30 cc Stock Tank Liquid (STL). The centrifuged STL had a density of 0.987 glee at 60°F, which had an API of 11.9. The centrifuged STL also had a water content of 8.5% wt%. I I I I I I I I I I I I I I I I I I I WCP Oilphase-DBR Prudhoe Bay Schlum_apta, 200400350 · · · · · · 6 Job #: 200400350 I I Client: Well: Insta lIation: BP S-213A Field: Sand: Job #: Prudhoe Bay Scblumbø.g8' 200400350 I Quality Assurance Process I Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment. I A rigorous quality assurance program, continuous employee training and enforcement of strict safety standards maintain our compliance with Duality, Health, Safety and Environment (QHSEI requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE policies and standards. Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures. Details of these programs are available upon request. I The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results I al Establish quality of measurement during data generation. bl Establish quality of processed data as per che¡;klist during data processing by Data Quality Engineer cl Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency dl The responsible Project Engineer confirms consistency of reported data el Engineering Project Manager review the resultslreport for overall consistency I Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity. All property measurements and calculation procedures are maintained in company archives for a period of 1 year. This information is available for review by clients upon request. I The file and laboratory records information are listed below to provide access reference to all records related to this project. For any questions, please do not hesitate to contact the undersigned Project Engineer. File No,: 200400350 Laboratory Records: 200400350 I Data Quality Data Reporting Suyu Ye Meisong Van I Data Quality Engineer Project Engineer Overall Report Quality I Dennis D'cruz I Dennis D'cruz Engineering Project Manager I I I I I I WCP Oilphase-DBR 7 Job #: 200400350 I I Client: BP Well: S-213A Installation: 200400350 Field: Sand: Job #: Prudhoe Bay Schlumblrg.. I Sequence of Events I I 12/21/04 12/21/04 12/22/04 12/22/04 01/13/04 01/25/05 02/04/05 02/11/05 02/18/05 02/22/05 I I I Samples arrived. Project work scope discussed. Work agreement approved. Prelim PVT tests request for all six samples issued. Sample PVT prelim results sent via e-mail. Sample PVT prelim results invoice sent Invoice#:9091333593. Bo, Pb results update and 1.11 PVT results update via e-mail. The viscosity results update for sample 1.01, 1.04, 1.08, 1.09 and 1.10 were sent via e-mail. The sample 1.12 results update were sent via e-mail. Sample PVT results invoice sent Invoice#:9091342894. Chain of Sample Custody The samples collected from the well S-213A were sentto Oilphase-DBR in Houston, Texas. The samples were used to preliminary measurements and subsequent PVT studies. The measurement details are in the following text Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. I I I I I I I I I I I WCP Oilphase-DBR 8 Job #: 200400350 I I Client: BP Well: S-213A Installation: Field: Sand: Job#: Prudhoe Bay Sell.RlbIPt. 200400350 RESUL IS AND DISCUSSIONS I Fluids Preparation and Analysis Ten bottom hole samples collected during the MDT were transferred to Oilphase-DBR. The well and formation data with their respective reservoir conditions for the bottomhole samples are summarized in Table 1. The quality check for the bottomhole samples were conducted and the results are summarized in Table 2. After 5-days of homogenization, sample validation test was conducted to evaluate the validity of the samples, and all the samples Were good candidates for PVT analysis. Based on the preliminary results, representative samples can selected for PVT analysis. The reservoir fluid and stock-tank oil properties for all the samples are presented in Table 3 and Table 4. I I Reservoir Fluid Analysis The gas and liquid from zero flash were subjected to chromatography and their compositions were determined. These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GaR) to calculate the reservoir fluid composition. The reservoir fluid analysis is summarized in Table 5, 7, 9, 11, 13, 15, 17, 19,21 and 23. The molecular weight of the stock-tank oil (STO) was measured. Other properties such as the plus fraction properties and heat content for the flash gas were calculated from the compositions and are listed in Table 6, 8,10,12,14,16,18,20,22 and 24. Sample 1.07 is a dry gas sample. I I The water-based mud was used for the reservoir completion. I I I I I I I I I I I I WCP Oilphase-DBR 9 Job #: 200400350 I I Client: BP Field: Prudhoe Bay SOhllRlbfJl'g. Well: S-213A Sand: Installation: Job #: 200400350 Table 1: Well and Sample Identification Client: BP Job# 200400350 Field: Prudhoe Bay Well: S-213A Sample ID Cylinder # Sand Sampling Date Reservoir Conditions Name Pressure Temperature MD TVD TVDSS Ipsia) 1°F) Iftl Iftl 1ft) 101 CSB 7759-QA OBd 11/30/04 2.594 104 6824 5258 -5196 102 CSB 7763-QA OBd 11/30/04 2.594 104 6824 5258 -5196 104 CSB 7476-MA OBa 11/30/04 2,523 101 6177 5130 -5068 105 CSB 7735-QA OBa 11/30/04 2,523 101 6177 5130 -5068 107 CSB 7753-QA OA-Upper 11/30/04 2.494 100 6000 5057 -4995 108 CSB 7755-QA OBe 11/30/04 2,558 103 6403 5190 -5128 1.09 CSB 7690-QA OBb 11/30/04 2,542 102 6247 5151 -5090 1.10 CSB 7761-QA OA-Lower 11/30/04 2.482 101 6059 5084 -5022 1.11 CSB 7725-QA Me 11/30/04 2.427 98 5747 4920 -4858 1.12 CSB 7680-QA Mb1 11/30/04 2,358 95 5531 4780 -4718 I I I I I I I I I I I I I I I I I WCP Oilphase-DBR 10 Job #: 200400350 I I Client: BP Field: Prudhoe Bay 8ehllll18PDer Well: S-213A Sand: Insta lIation: Job #: 200400350 Table 2: Sampling and Transfer Summary Transfer Opening Opening Initial Final Sample ID Chamber # Sand Cylinder cond itions cond itions BS&W Sample Sample Name 10 in the field in the Lab Volume Volume (psia¡OFI (psia¡OF) (%, v/v) Ice) leel 1.01 MRSC 242 OBd CSB 7759-QA 1965/62 1265/78 0 600 blowdown 102 MRSC 242 OBd CSB 7763-QA 1965/62 1415/78 0 600 550 1.04 MRSC 292 OBa CSB 7476-MA 2165/61 1215/81.3 1.5 600 blowdown 1.05 MRSC 292 OBa CSB 7735-QA 2165/61 1215/81.3 1 600 550 1.07 MPSR 1397 OA-Upper CSB 7753-QA 3515/62 95151775 420 340 1.08 MPSR 1398 OBe CS B 7755-QA 2265/62 1415/81.3 0 420 blowdown 1.09 MPSR 1399 OBb CS B 7690-QA 2115/62 1215/81.3 0.5 420 blowdown 1.10 MPSR 1400 OA-Lower CSB 7761-QA 2215/61 1215/81.3 0.5 420 blowdown 1.11 MPSR 1401 Me CSB 7725-QA 2165/61 915178 Trace 420 120 1.12 MPSR 1402 Mb1 CS B 7680-QA 2265/61 765178 1 420 blowdown I I I I I I I I I I I I I I I I I WCP Oilphase-OBR 11 Job #: 200400350 I I Client: BP Field: Prudhoe Bay 8e_b8POer Well: S-213A Sand: Insta lIation: Job#: 200400350 Table 3: Reservoir fluid Properties Zero Flash Saturation Molar Mass of Viscosity of Sample ID Cylinder # Sand MD TVDSS GOR* Bo** Pressure monophasic Res. Fluid Name atTres fluid at Pres, T res (ft) 1ft) (scf/stb) (psial (cPI 1.01 CSB 7759-ClA DBd 6824 -5196 310 1.147 2013 166.9 8.0 102 CSB 7763-ClA DBd 6824 -5196 307 167.8 N/D 1.04 CSB 7476-MA DBa 6177 -5068 234 1.102 1987 212.2 31.4 1.05 CSB 7735-ClA DBa 6177 -5068 225 215.2 N/D 1.07 CSB 7753-ClA DA-Upper 6000 -4995 15,670 23.5 N/D 1.08 CSB 7755-ClA DBc 6403 -5128 291 1.137 1947 16B.5 11.9 1.09 CSB 7690-ClA DBb 6247 -5090 260 1.113 1884 183.7 12.7 1.10 CSB 7761-ClA DA-Lower 6059 -5022 212 1.091 1836 209.2 28.2 1.11 CSB 7725-ClA Mc 5747 -4858 194 1.065 1818 278.5 294.4 1.12 CSB 768o-ClA Mb1 5531 -4718 203 1.058 1769 281.7 Not Enough VoL * Flashed gas volume (scf) per barrel of stock tank liquid @ 60°F ** Volume of live oil at it's bubble point pressure per flashed stock tank liquid volume @ 60°F I I I I I I I I I I I I I I I I I WCP Oilphase-DBR 12 Job #: 200400350 I I Client: BP Field: Prudhoe Bay SclllllllberRep Well: S-213A Sand: Insta lIation: Job #: 200400350 Table 4: Stock-Tank Oil Properties SID Properties Sample ID Cylinder # Sand MD TVDSS Molar Mass Density API Name (ftl (ft) (glee) 101 CSB 7759-QA OBd 6824 -5,196 268.3 0.910 24.1 102 CSB 7763-QA OBd 6824 -5,196 269.1 0.910 24.0 1.04 CSB 7476-MA OBa 6177 -5,068 332.5 0.941 18.8 1.05 CSB 7735-QA OBa 6177 -5,068 333.2 0.942 18.8 1.07 CSB 7753-QA OA-Upper 6000 -4,995 175.0 0.836 37.7 1.08 CSB 7755-QA OBe 6403 -5,128 263.0 0.907 24.5 1.09 CSB 769O-QA OBb 6247 -5,090 282.7 0.917 22.8 1.10 CSB 7761-QA OA-Lower 6059 -5,022 308.9 0.936 19.7 1.11 CSB 7725-QA Me 5747 -4,858 457.9 0.972 14.0 1.12 CSB 768o-QA Mb1 5531 -4)18 480.4 0.980 12.9 I I I I I I I I I I I I I I I I I WCP Oilphase-DBR 13 Job #: 200400350 I I Client: BP Field: Prudhoe Bay Schlumberger Well: S-213A Sand: OBd I Table 5: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.01) Sample#: 1.01; CSB 7759-0A; OBd Sand; MO = 6824 ft; TVO = 5258 ft; TVOSS = -5196 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (gjmole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 1.85 0.82 0.00 0.00 0.09 0.33 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.29 0.20 0.00 0.00 0.01 0.08 Methane 16.04 72.62 87.73 0.00 0.00 3.44 35.74 Ethane 30.07 9.82 6.33 0.00 0.00 0.46 2.58 Propane 44.10 3.85 1.69 0.02 0.11 0.20 0.75 I I - Butane 58.12 2.10 0.70 0.02 0.11 0.12 0.35 N - Butane 58.12 2.47 0.82 0.05 0.21 0.16 0.46 I - Pentane 72.15 1.86 0.50 0.11 0.39 0.19 0.44 I N - Pentane 72.15 1.55 0.42 0.13 0.46 0.19 0.45 C6 84.00 1.68 0.39 0.49 1.56 0.54 1.08 M-C-Pentane 84.16 0.43 0.10 0.24 0.77 0.25 0.50 I Benzene 78.11 0.03 0.01 0.02 0.07 0.02 0.04 Cyclohexane 84.16 0.35 0.08 0.37 1.19 0.37 0.74 C7 96.00 0.51 0.10 0.96 2.69 0.94 1.64 M-C-Hexane 98.19 0.31 0.06 1.13 3.08 1.09 1.85 I Toluene 92.14 0.01 0.00 0.05 0.14 0.05 0.08 C8 107.00 0.14 0.02 1.83 4.60 1.75 2.73 E-Benzene 106.17 0.00 0.00 0.16 0.40 0.15 0.24 I MjP-Xylene 106.17 0.01 0.00 0.31 0.78 0.29 0.46 a-Xylene 106.17 0.00 0.00 0.20 0.51 0.19 0.30 C9 121.00 0.06 0.01 2.13 4.72 2.03 2.80 I C10 134.00 0.03 0.01 3.27 6.54 3.12 3.88 C11 147.00 0.01 0.00 2.80 5.12 2.67 3.03 C12 161.00 0.00 0.00 3.22 5.36 3.06 3.18 C13 175.00 0.00 0.00 3.43 5.26 3.27 3.11 I C14 190.00 0.00 0.00 3.76 5.31 3.58 3.15 C15 206.00 0.00 0.00 3.64 4.74 3.47 2.81 C16 222.00 3.44 4.16 3.28 2.47 I C17 237. 00 3.04 3.44 2.90 2.04 C18 251.00 3.39 3.62 3.23 2.15 C19 263.00 3.20 3.27 3.05 1.94 I C20 275.00 2.69 2.62 2.56 1.55 C21 291.00 2.70 2.49 2.58 1.48 C22 300.00 2.41 2.15 2.29 1.28 C23 312.00 2.29 1.97 2.19 1.17 I C24 324.00 2.28 1.88 2.17 1.12 C25 337.00 2.12 1.69 2.02 1.00 C26 349.00 1.90 1.46 1.81 0.86 I C27 360.00 1.88 1.40 1.79 0.83 C28 372.00 1.77 1.27 1.68 0.75 C29 382.00 1.95 1.37 1.86 0.81 I C30+ 750.00 36.61 13.10 34.88 7.76 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 19.38 268.25 166.86 MOLE RATIO 0.4074 0.5926 I I WCP Oilphase-DBR 14 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBd Schlumberger Properties Table 6: Calculated Fluid Properties Sample#: 1.01; CSB 7759-QA; OBd Sand; MD = 6824 ft; TVD = 5258 ft; TVDSS = -5196 ft Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole % C7+ 1.90 0.40 99.20 97.16 94.59 57.74 C12+ 0.00 0.00 85.72 66.57 81.67 39.45 C20+ 58.60 31.41 55.82 18.61 C30+ 36.61 13.10 34.88 7.76 Molar Mass C7+ 92.47 273. 86 273.35 C12+ 345.44 345.44 C20+ 500.45 500.45 C30+ 750.00 750.00 Density C7+ 0.9127 C12+ 0.9394 0.9394 C20+ 0.9967 0.9967 C30+ 1.0794 1.0794 Fluid at 60°F 0.9096 Gas Gravity (Air = 1) 0.669 Dry Gross Heat Content (BTU/scf) I 1,167 Wet Gross Heat Content (BTU/scf) 1,146 OBM Contamination level (wt%) ISTO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 266.14 268.25 I 750.00 I Density (g/cm3) 0.910 1.079 Single Stage Flash Data Original STO De-Contaminated GOR (scf!stb) 310 I STO Density (g/cm3) 0.9096 STO API Gravity 24.1 OBM Density (g/cm3) @60°F WCP Oilphase-DBR 15 Job #: 200400350 I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBd Figure 1: Stock Tank Oil Chromatogram (Sample 1.01) Sample#: 1.01; CSB 7759-QA; OBd Sand; MO == 6824 ft; TVD == 5258 ft; TVOSS == -5196 it 600 - 600 - I.() l) S ~ ,-, ~ ¡¡;;. '100- 300 - 100- I 10 I 20 I 30 I '10 I 60 min 200 - Figure 2: k-Plot for Equilibrium Check (Sample 1.()1) Sample#: 1.01; CSB 7759-QA; OBd Sand: MO == 6824 ft; TVD == 5258 ft; TVDSS == -5196 ft JOO 2.50 . C3 200 . 1.50 100 '*' 0.50 ~d-:6 000 '*' Cì -0.50 . C8 -100 -1.50 <$> C::I -200 . Cl0 -2.50 -JOO -2.00 -100 0.00 100 200 JOO F WCP Oilphase-DBR 16 Job it. 200400350 I Client: BP Field: Prudhoe Bay Scblumberuer I Well: S-213A Sand: OBd I Table 7: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.02) Sample#: 1.02; CSB 7763-0A; OBd Sand; MD = 6824 ft; TVD = 5258 ft; TVDSS = -5196 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 1.82 0.80 0.00 0.00 0.09 0.33 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.28 0.19 0.00 0.00 0.01 0.08 I Methane 16.04 72.15 87.49 0.00 0.00 3.39 35.50 Ethane 30.07 9.88 6.39 0.00 0.00 0.46 2.59 Propane 44.10 4.08 1.80 0.01 0.09 0.21 0.78 I I - Butane 58.12 2.15 0.72 0.02 0.09 0.12 0.35 N - Butane 58.12 2.63 0.88 0.04 0.19 0.16 0.47 I - Pentane 72.15 1.91 0.52 0.10 0.38 0.19 0.43 I N - Pentane 72.15 1.63 0.44 0.12 0.45 0.19 0.45 C6 84.00 1.69 0.39 0.46 1.48 0.52 1.04 M-C-Pentane 84.16 0.40 0.09 0.24 0.75 0.24 0.49 I Benzene 78.11 0.03 0.01 0.02 0.07 0.02 0.04 Cyclohexane 84.16 0.27 0.06 0.37 1.19 0.37 0.73 C7 96.00 0.54 0.11 0.95 2.67 0.93 1.63 M-C-Hexane 98.19 0.25 0.05 1.13 3.10 1.09 1.86 I Toluene 92.14 0.06 0.01 0.05 0.14 0.05 0.09 C8 107.00 0.12 0.02 1.84 4.62 1.76 2.76 E-Benzene 106.17 0.00 0.00 0.16 0.41 0.15 0.24 I M/P-Xylene 106.17 0.01 0.00 0.31 0.79 0.30 0.47 O-Xylene 106.17 0.00 0.00 0.20 0.51 0.19 0.31 C9 121.00 0.06 0.01 2.15 4.77 2.05 2.84 I C10 134.00 0.03 0.00 3.30 6.62 3.14 3.94 C11 147.00 0.01 0.00 2.83 5.17 2.69 3.07 C12 161.00 0.00 0.00 3.24 5.42 3.09 3.22 C13 175.00 0.00 0.00 3.45 5.31 3.29 3.15 I C14 190.00 0.00 0.00 3.78 5.35 3.60 3.18 C15 206.00 0.00 0.00 3.64 4.76 3.47 2.83 C16 222.00 3.43 4.16 3.27 2.47 I C17 237.00 3.03 3.44 2.89 2.04 C18 251.00 3.36 3.60 3.20 2.14 C19 263. 00 3.16 3.23 3.01 1.92 I C20 275.00 2.64 2.59 2.52 1.54 C21 291.00 2.67 2.47 2.54 1.47 C22 300.00 2.31 2.08 2.21 1.23 C23 312.00 2.24 1.93 2.14 1.15 I C24 324.00 2.21 1.84 211 1.09 C25 337.00 2.25 1.80 2.15 1.07 C26 349.00 1.65 1.27 1.57 0.76 I C27 360.00 1.79 1.34 1.71 0.80 C28 372.00 1.73 1.25 1.65 0.74 C29 382.00 1.89 1.33 1.80 0.79 I C30+ 750.00 37.22 13.35 35.47 7.93 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 19.45 269.05 167.77 MOLE RATIO 0.4058 0.5942 I WCP Oilphase-DBR 17 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBd Schlumberger Properties Table 8: Calculated Fluid Properties Sample#: 1.02; CSB 7763-QA; OBd Sand; MD = 6824 ft; TVD = 5258 ft; TVDSS = -5196 ft Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole% C7+ 1.78 0.37 99.24 97.32 94.65 57.98 C12+ 0.00 0.00 85.69 66.49 81.66 39.51 C20+ 58.62 31.24 55.86 18.57 C30+ 37.22 13.35 35.47 7.93 Molar Mass C7+ 92.78 274.36 273.89 C12+ 161.00 346.76 346.76 C20+ 504.73 504.73 C30+ 750.00 750.00 Density C7+ 0.9127 C12+ 0.9395 0.9395 C20+ 0.9967 0.9967 C30+ 1.0757 1.0757 Fluid at 60°F 0.9097 Gas Gravity (Air = 1) 0.672 Dry Gross Heat Content (BTU/scf) I 1,171 Wet Gross Heat Content (BTU/scf) 1,151 OBM Contamination level (wt%) STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 271.18 269.05 I 750.00 I Density (g/cm3) 0.910 1.076 Single Stage Flash Data Original STO De-Contami nated GOR (scf!stb) 307 I STO Density (g/cm3) 0.9097 STO API Gravity 24.0 OBM Density (g/cm3) @60°F WCP Oilphase-DBR 18 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay DBd Figure 3: Stock Tank Oil Chromatogram (Sample 1.(2) Sample#: 1.02; CSB 7763-QA; OBd Sand; MD = 6824 ft; TVD = 5258 ft; TVDSS = -5196 ft (D ü , o () ), () ¿ I 10 I 20 I 30 'iO I 50 Figure 4: k-Plot for Equilibrium Check (Sample UJ2) Sample#: 1.02; CSB 7763-QA; OBd Sand; MD = 6824 ft; TVD = 5258 ft; TVDSS = -5196 ft 300 2.50 200 1.50 1.00 0.50 000 -0.50 -1.00 -¡50 -2.00 -2.50 -2.00 '" iC4 . nC4 ~ . C7 . C8 -1.50 -100 -0.50 000 0.50 100 150 200 2.50 300 F WCP Oilphase-DBR 19 Job #: 200400350 I Client: BP Field: Prudhoe Bay SchlumbergBr I Well: S-213A Sand: DBa I Table 9: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.04) Sample#: 1.04; CSB 7476-MA; OBa Sand; MD = 6177 ft; TVD = 5130 ft; TVDSS = -5068 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 4.52 1.89 0.00 0.00 0.15 0.72 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.83 0.55 0.00 0.00 0.03 0.21 I Methane 16.04 78.96 90.67 0.00 0.00 2.62 34.72 Ethane 30.07 7.26 4.45 0.00 0.00 0.24 1.70 Propane 44.10 1.69 0.71 0.01 0.07 0.06 0.31 I I - Butane 58.12 0.88 0.28 0.01 0.05 0.04 0.14 N - Butane 58.12 1.47 0.47 0.02 0.14 0.07 0.27 I - Pentane 72.15 0.74 0.19 0.04 0.17 0.06 0.18 I N - Pentane 72.15 1.01 0.26 0.08 0.35 0.11 0.31 C6 84.00 0.94 0.21 0.21 0.82 0.23 0.59 M-C-Pentane 84.16 0.33 0.07 0.11 0.45 0.12 0.31 I Benzene 78.11 0.01 0.00 0.01 0.02 0.01 0.01 Cyclohexane 84.16 0.22 0.05 0.13 0.53 0.14 0.35 C7 96.00 0.28 0.05 0.35 1.20 0.34 0.76 M-C-Hexane 98.19 0.21 0.04 0.27 0.92 0.27 0.58 I Toluene 92.14 0.40 0.08 0.07 0.25 0.08 0.18 C8 1 07. 00 0.15 0.D3 0.56 1.75 0.55 1.09 E-Benzene 106.17 0.00 0.00 0.04 0.13 0.04 0.08 I M/P-Xylene 106.17 0.01 0.00 0.08 0.24 0.07 0.15 O-Xylene 106.17 0.00 0.00 0.05 0.16 0.05 0.10 C9 121.00 0.07 0.01 0.78 2.15 0.76 1.33 I C10 134.00 0.00 0.00 1.46 3.63 1.42 2.24 C11 147.00 0.00 0.00 1.71 3.87 1.65 2.39 C12 161. 00 0.00 0.00 2.35 4.85 2.27 2.99 C13 175.00 0.00 0.00 2.87 5.45 2.78 3.37 I C14 190.00 0.00 0.00 3.34 5.85 3.23 3.61 C15 206.00 0.00 0.00 3.47 5.60 3.36 3.46 C16 222.00 3.27 4.90 3.17 3.03 I C17 237.00 3.40 4.77 3.28 2.94 C18 251.00 3.01 3.99 2.91 2.46 C19 263.00 2.86 3.61 2.76 2.23 I C20 275.00 2.74 3.32 2.65 2.05 C21 291. 00 2.75 3.14 2.65 1.94 C22 300.00 2.52 2.80 2.44 1.73 C23 312.00 2.29 2.44 2.21 1.51 I C24 324.00 2.30 2.36 2.22 1.46 C25 337.00 2.17 2.14 2.10 1.32 C26 349.00 1.93 1.84 1.87 1.14 I C27 360.00 1.94 1.79 1.87 1.10 C28 372.00 1.85 1.66 1.79 1.02 C29 382.00 2.12 1.84 2.04 1.14 I C30+ 750.00 46.82 20.76 45.27 12.81 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 18.42 332.48 212.23 MOLE RATIO 0.3829 0.6171 I WCP Oilphase-DBR 20 Job #: 200400350 I I I CI ient: BP Field: Prudhoe Bay Schlumbepgep Well: S-213A Sand: OBa I Table 10: Calculated Fluid Properties Sample#: 1.04; CSB 7476-MA; OBa Sand; MD = 6177 ft; TVD = 5130 ft; TVDSS = -5068 ft Properties Flashed Gas Flashed liquid Monophasic Fluid I Cn+ Composition Mass % Mole% Mass % Mole % Mass % Mole % C7+ 1.68 0.33 99.64 98.40 96.38 60.85 I C12+ 0.00 0.00 94.01 83.11 90.89 51.29 C20+ 69.43 44.08 67.13 27.20 C30+ 46.82 20.76 45.27 12.81 I Molar Mass C7+ 92.75 336.66 336.15 C12+ 376.09 376.09 I C20+ 523.77 523.77 C30+ 750.00 750.00 I Density C7+ 0.9429 C12+ 0.9553 0.9553 C20+ 1.0055 1. 0055 I C30+ 10770 10770 Fluid at 60°F 0.9413 I Gas Gravity (Air = 1) 0.636 Dry Gross Heat Content (BTU/scf) I 1,082 I Wet Gross Heat Content (BTU/scf) 1,063 OBM Contamination level (wt%) ISTO Basis I Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 338.77 332.48 I 750.00 I I Density (g/cm3) 0.941 1.077 Single Stage Flash Data I Original STO De-Contami nated GOR (scf!stb) 234 I STO Density (g/cm3! 0.9413 I STO API Gravity 18.8 OBM Density (g/cm3) @60°F 0.0000 I I I I WCP Oilphase-DBR 21 Job #: 200400350 I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay DBa Figure 5: Stock: Tank: Oil Chromatogram (Sample 1.(4) Sample#: 1.04; CSB 7476-MA; OBa Sand; MO = 6177 ft; TVO = 5130 ft; TVOSS = -5068 ft 500 400 - 300 - 100 - 1 10 1 20 1 30 1 40 1 50 min 200 - o o Figure 6: k-Plot for Equilibrium Check: (Sample 1.(4) Sample#: 1.04; CSB 7476-MA; OBa Sand; MO = 6177 ft; TVO = 5130 ft; TVOSS = -5068 ft I I I Iii I I I 2.50 . C3 2.00 . iC4 . nC4 1.50 ... IC5 100 0.50 0.00 .. -0.50 -100 . C9 -1.50 -2.50 -2.00 -1.50 -100 -0.50 000 0.50 100 1.50 200 2.50 300 F WCP Oilphase-DBR 22 Job #: 200400350 I Client: BP Field: Prudhoe Bay Scblumbepgep I Well: S-213A Sand: OBa I Table 11: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.05) Sample#: 1.05; CSB 7735-0A; aBa Sand; MO = 6177 ft; TVO = 5130 ft; TVOSS = -5068 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (g/mole WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 4.52 1.88 0.00 0.00 0.14 0.71 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.30 0.19 0.00 0.00 0.01 om Methane 16.04 79.69 91.07 0.00 0.00 2.54 34.13 Ethane 30.07 7.33 4.47 0.00 0.00 0.23 1.67 Propane 44.10 1.70 0.71 0.01 0.07 0.06 0.31 I I - Butane 58.12 0.87 0.27 0.01 0.05 0.04 0.14 N - Butane 58.12 1.45 0.46 0.03 0.14 0.07 0.26 I - Pentane 72.15 0.74 0.19 0.04 0.17 0.06 0.17 I N - Pentane 72.15 0.98 0.25 0.08 0.39 0.11 0.34 C6 84.00 1.14 0.25 0.27 1.07 0.30 0.76 M-C-Pentane 84.16 0.32 0.07 0.12 0.49 0.13 0.33 I Benzene 78.11 0.01 0.00 0.01 0.02 0.01 0.01 Cyclohexane 84.16 0.19 0.04 0.13 0.52 0.13 0.34 C7 96.00 0.26 0.05 0.34 1.19 0.34 0.76 M-C-Hexane 98.19 0.15 003 0.27 0.90 0.26 0.57 I Toluene 92.14 0.21 0.04 0.09 0.34 0.10 0.23 C8 107.00 0.10 0.02 0.56 1.74 0.55 1.10 E-Benzene 106.17 0.00 0.00 0.04 0.13 0.04 0.08 I M/P-Xylene 106.17 0.00 0.00 0.07 0.23 0.07 0.15 a-Xylene 106.17 0.00 0.00 0.05 0.15 0.05 0.10 C9 121.00 003 0.01 0.77 2.11 0.74 1.32 I C10 134.00 0.00 0.00 1.44 3.57 1.39 2.23 C11 147.00 0.00 0.00 1.68 3.81 1.63 2.38 C12 161.00 0.00 0.00 2.32 4.80 2.24 3.00 C13 175.00 0.00 0.00 2.84 5.41 2.75 3.38 I C14 190.00 0.00 0.00 3.32 5.82 3.21 3.64 C15 206.00 0.00 0.00 3.46 5.59 3.35 3.49 C16 222.00 3.26 4.90 3.16 3.06 I C17 237.00 3.39 4.76 3.28 2.98 C18 251.00 3.00 3.98 2.90 2.49 C19 263. 00 2.85 3.61 2.76 2.25 I C20 275.00 2.72 3.30 2.64 2.06 C21 291.00 2.74 3.14 2.65 1.96 C22 300.00 2.48 2.76 2.40 1.72 C23 312.00 2.27 2.43 2.20 1.52 I C24 324.00 2.18 2.24 2.11 1.40 C25 337.00 1.98 1.95 1.91 1.22 C26 349.00 2.08 1.98 2.01 1.24 I C27 360.00 1.96 1.82 1.90 1.14 C28 372.00 1.94 1.74 1.88 1.09 C29 382.00 1.91 1.67 1.85 1.04 I C3O+ 750.00 47.30 21.01 45.79 13.14 Total 100.00 100,00 100.00 100.00 100.00 100.00 MW 18.33 333.16 215.19 MOLE RATIO 0.3747 0.6253 I WCP Oilphase-DBR 23 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBa Schlumberler Properties Table 12: Calculated Fluid Properties Sample#: 1.05; CSB 7735-0A; OBa Sand; MD = 6177 ft; TVD = 5130 ft; TVDSS = -5068 ft Flashed Gas Flashed liquid Monophasic Fluid Cn+ Composition Mass % Mole% Mass % Mole% Mass % Mole % C7+ 1.29 0.26 99.57 98.11 96.43 61.44 C12+ 0.00 0.00 93.99 82.89 90.99 51.83 C2O+ 69.57 44.03 67.34 27.53 C3O+ 47.30 21.01 45.79 13.14 Molar Mass C7+ 91.74 338.11 337.73 C12+ 377.80 377.80 C2O+ 526.37 526.37 C3O+ 750.00 750.00 Density C7+ 0.9434 C12+ 0.9557 0.9557 C20+ 1.0056 1.0056 C3O+ 1.0753 1.0753 FI uid at 60°F 0.9415 Gas Gravity (Air = 1) 0.633 Dry Gross Heat Content (BTU/scf) I 1,084 Wet Gross Heat Content (BTU/scf) 1,065 OBM Contamination level (wt%) ISTO Basis Live Oi I Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 335.79 333.16 I 750.00 I Density (g/cm3! 0.942 1.075 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 225 I STO Density (g/cm3! 0.9415 STO API Gravity 18.8 OBM Density (g/cm3) @6o°F WCP Oilphase-DBR 24 Job #: 200400350 I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBa Figure 1: Stock Tank Oil Chromatogram (Sample 1.05) Sample#: 1.05; CSB 7735-QA; OBa Sand; MD = 6177 ft; TVD = 5130 ft; TVDSS -5068 ft 700 - 600 - 500 - 400- 300 - I 10 I 20 I 30 I 40 I 50 I I I I Figure 8: k-Plot for Equilibrium Check (Sample 1.05) Sample#: 1.05; CSB 7735-QA; OBa Sand; MD = 6177 ft; TVD = 5130 ft; TVDSS = -5068 ft 2.50 . C3 2.00 .. 1.50 . ìC5 100 0.50 '" C6 000 . C7 -050 .. C8 -100 -150 -200 -2.50 -200 -1.50 -100 -0.50 0.00 0.50 100 1.50 200 2.50 300 F WC!' Oilphase-DBR 25 Job #: 200400350 I CI ient: BP Field: Prudhoe Bay Scblumberger I Well: S-213A Sand: OA-Upper I Table 13: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.07) Sample#: 1.07; CSB 7753-0A; OA-Upper Sand; MO = 6000 ft; TVO = 5057 ft; TVOSS = -4995 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 1.80 0.71 0.00 0.00 1.28 0.68 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 1.24 0.76 0.00 0.00 0.88 0.74 I Methane 16.04 89.01 96.01 0.00 0.00 63.12 92.26 Ethane 30.07 2.02 1.16 0.00 0.00 1.43 1.11 Propane 44.10 0.41 0.16 0.00 0.01 0.29 0.16 I I - Butane 58.12 0.35 0.10 0.01 0.02 0.25 0.10 N - Butane 58.12 0.61 0.18 0.02 0.07 0.44 0.18 I - Pentane 72.15 0.52 0.12 0.08 0.20 0.39 0.13 I N - Pentane 72.15 0.61 0.15 0.15 0.37 0.48 0.15 C6 84.00 1.18 0.24 1.17 2.44 1.18 0.33 M-C-Pentane 84.16 0.34 0.07 0.55 1.15 0.41 0.11 I Benzene 78.11 0.01 0.00 0.01 0.02 0.01 0.00 Cyclohexane 84.16 0.22 0.05 0.65 1.34 0.34 0.10 C7 96.00 0.59 0.11 2.60 4.74 1.18 0.29 M-C-Hexane 98.19 0.32 0.06 1.89 3.36 0.78 0.19 I Toluene 92.14 0.05 0.01 0.30 0.58 0.12 0.03 C8 1 07. 00 0.32 0.05 5.02 8.21 1.69 0.37 E-Benzene 106.17 0.01 0.00 0.19 0.32 0.06 0.01 I M/P-Xylene 106.17 0.02 0.00 0.47 0.78 0.15 0.03 a-Xylene 106.17 0.01 0.00 0.31 0.51 0.10 0.02 C9 121.00 0.23 0.03 5.77 8.35 1.84 0.36 I C10 134.00 0.08 0.01 7.05 9.20 2.11 0.37 C11 147.00 0.03 0.00 6.63 7.90 1.95 0.31 C12 161.00 0.00 0.00 6.91 7.51 2.01 0.29 C13 175.00 0.00 0.00 7.21 7.20 2.10 0.28 I C14 190.00 0.00 0.00 6.84 6.30 1.99 0.25 C15 206.00 0.00 0.00 6.63 5.63 1.93 0.22 C16 222.00 5.30 4.17 1.54 0.16 I C17 237.00 4.55 3.36 1.32 0.13 C18 251.00 4.39 3.06 1.28 0.12 C19 263.00 3.58 2.38 1.04 0.09 I C20 275.00 3.06 1.95 0.89 0.08 C21 291.00 2.69 1.62 0.78 0.06 C22 300.00 2.42 1.41 0.70 0.06 C23 312.00 1.98 1.11 0.58 0.04 I C24 324.00 2.00 1.08 0.58 0.04 C25 337.00 1.01 0.52 0.29 0.02 C26 349.00 1.34 0.67 0.39 0.03 I C27 360.00 1.31 0.64 0.38 0.02 C28 372.00 1.02 0.48 0.30 0.02 C29 382.00 0.95 0.44 0.28 0.02 I C30+ 750.00 3.94 0.92 1.14 0.04 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.30 174.96 23.45 MOLE RATIO 0.9610 0.0390 I WCP Oilphase-DBR 26 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OA-Upper Scblumberger Table 14: Calculated Fluid Properties Sample#: 1.07; CSB 7753-0A; OA-Upper Sand; MO = 6000 ft; TVO = 5057 ft; TVOSS = -4995 ft Properties Flashed Gas Flashed liquid Monophasic Fluid Cn+ Composition Mass % Mole% Mass % Mole % Mass % Mole % C7+ 2.24 DAD 98. 56 96.90 30.26 4.16 C12+ 0.00 0.00 67.12 50.45 19.52 1.97 C20+ 21.72 10.83 6.32 OA2 C30+ 3.94 0.92 1.14 0.04 Molar Mass C7+ 97.90 177.97 170.63 C12+ 232.77 232.77 C20+ 350.77 350.77 C30+ 750.00 750.00 Density C7+ 0.8396 C12+ 0.8770 0.8770 C2ü+ 0.9883 0.9883 C30+ 21973 2.1973 Fluid at 60°F 0.8362 Gas Gravity (Air = 1) 0.597 Dry Gross Heat Content (BTU/scf) I 1,049 Wet Gross Heat Content (BTU/scf) 1,030 OBM Contamination level (wt%) ISTO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 1 174.96 I 750.00 I Density (g/cm3) 0.836 2.197 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 15670 I STO Density (g/cm3) 0.8362 STO API Gravity 37.7 OBM Density (g/cm3) @60°F WCP Oilphase-DBR 27 Job #: 200400350 I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OA-Upper Figure 9: Stock Tank Oil Chromatogram (Sample 1.(1) Sample#: 1.07; CSB 7753-QA; OA-Upper Sand; MD 6000 ft; TVD = 5057 ft; TVDSS = -4995 ft üJ o I o l' >, U ¿: 10 15 20 I 30 35 min I I Figure 10: k-Plot for Equilibrium Check (Sample 1.07) Sample#: 1.07: CSB 7753-QA; OA-Upper Sand; MD = 6000 ft; TVD 5057 ft; TVDSS = -4995 ft I I I 3.00 250 . C3 200 . ìC4 1.50 . n~4 1.00 . 050 0.00 . C6 -050 -1.00 . " C9 -150 . C10 -200 -2.50 -3.00 -200 -100 000 1.00 2.00 3.00 F I I WCP Oilphase-DBR 28 Job #: 200400350 I I Client: BP Field: Prudhoe Bay Scblumberger Well: S-213A Sand: OBc I Table 15: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.08) Sample#: 1.08; CSB 7755-0A; OBc Sand; MD = 6403 ft; TVD = 5190 ft; TVDSS = -5128 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 2.18 0.97 0.00 0.00 0.10 0.38 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.33 0.23 0.00 0.00 0.01 0.09 Methane 16.04 72.63 88.70 0.00 0.00 3.28 34.43 Ethane 30.07 8.21 5.35 0.00 0.00 0.37 2.08 Propane 44.10 1.31 0.58 0.01 0.04 0.07 0.25 I I - Butane 58.12 1.72 0.58 0.02 0.07 0.09 027 N - Butane 58.12 2.41 0.81 0.04 0.19 0.15 0.43 I - Pentane 72.15 2.58 0.70 0.14 0.50 0.25 0.58 I N - Pentane 72.15 3.21 0.87 0.23 0.84 0.36 0.85 C6 84.00 2.82 0.66 0.80 2.50 0.89 1.78 M-C-Pentane 84.16 0.60 0.14 0.29 0.91 0.31 0.61 I Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 0.40 0.09 0.39 1.22 0.39 0.78 C7 96.00 0.83 0.17 1.29 3.54 1.27 2.23 M-C-Hexane 98.19 0.38 0.08 0.92 2.46 0.90 1.54 I Toluene 92.14 0.05 0.01 0.06 0.16 0.06 0.10 C8 107.00 0.24 0.04 2.09 5.14 2.01 3.16 E-Benzene 106.17 0.00 0.00 0.13 0.31 0.12 0.19 I M/P-Xylene 106.17 0.01 0.00 0.32 0.80 0.31 0.49 a-Xylene 106.17 0.00 0.00 0.17 0.42 0.16 0.26 C9 121.00 0.06 0.01 2.35 5.11 2.25 3.13 I C10 134.00 0.01 0.00 3.24 6.36 3.09 3.89 C11 147.00 0.00 0.00 3.13 5.59 2.98 3.42 C12 161. 00 0.00 0.00 3.17 5.18 3.03 3.17 C13 175.00 0.00 0.00 3.48 5.24 3.33 3.20 I C14 190.00 0.00 0.00 3.56 4.92 3.40 3.01 C15 206.00 0.00 0.00 3.62 4.63 3.46 2.83 C16 222.00 3.21 3.80 3.06 2.33 I C17 237.00 2.86 3.18 2.74 1.94 C18 251.00 3.32 3.48 3.17 2.13 C19 263.00 2.79 2.79 2.67 1.71 I C20 275.00 2.72 2.60 2.60 1.59 C21 291.00 2.66 2.41 2.54 1.47 C22 300.00 2.29 2.01 2.19 1.23 C23 312.00 2.28 1.92 2.18 1.18 I C24 324.00 2.35 1.90 2.24 1.17 C25 337.00 2.13 1.66 2.03 1.02 C26 349.00 1.79 1.35 1.71 0.82 I C27 360.00 1.84 1.34 1.75 0.82 C28 372.00 1.71 1.21 1.64 0.74 C29 382.00 1.89 1.30 1.80 0.80 I C30+ 750.00 36.70 12.87 35.05 7.87 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 19.59 263.03 168.52 MOLE RATIO 0.3882 0.6118 I WCP Oilphase-DBR 29 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBe Schlumberger Properties Table 16: Calculated Fluid Properties Sample#: 1.08; CSB 7755-0A; OBc Sand; MD = 6403 ft; TVD = 5190 ft; TVDSS = -5128 ft Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole % C7+ 2.61 0.55 98.77 95.86 94.43 58.86 C12+ 0.00 0.00 84.39 63.81 80.58 39.04 C20+ 58.36 30.58 55.73 18.71 C30+ 36.70 12.87 35.05 7.87 Molar Mass C7+ 92.57 271.00 270.35 C12+ 347.86 347.86 C20+ 501.94 501.94 C30+ 750.00 750.00 Density C7+ 0.9116 C12+ 0.9410 0.9410 C20+ 0.9974 0.9974 C30+ 1.0793 1.0793 Fluid at 60°F 0.9070 Gas Gravity (Air = 1! 0.676 Dry Gross Heat Content (BTU/sef) I 1,174 Wet Gross Heat Content (BTU/scf! 1,153 OBM Contamination level (wt%) ISTO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 266.34 263. 03 I 750.00 I Density (g/em3! 0.907 1.079 Single Stage Flash Data Original STO De-Contaminated GOR (sef!stb) 291 I STO Density (g/em3) 0.9070 STO API Gravity 24.5 OBM Density (g/em3) @60°F WCP Oilphase-DBR 30 Job #: 200400350 I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBc Figure 11: Stock Tank Oil Chromatogram (Sample 1.08) Sample#: 1.08; CSB 7755-0A; aBc Sand; MD 6403 ft; TVD = 5190 ft; TVDSS -5128 ft o ,.. .,.0 ,.. () I 10 I 20 30 I 40 I 50 mìn Figure 12: k-Plot for Equilibrium Check (Sample 1.08) Sample#: 1.08; CSB 7755-QA; aBc Sand; MD 6403 ft; TVD = 5190 ft; TVDSS = -5128 ft I 2.50 200 150 100 0.50 0.00 -0.50 -100 -1.50 -200 -2.50 -2.00 + C3 . nC4 . . C6 . C7 . C8 -1.50 -100 -050 000 0.50 100 150 200 2.50 300 f I WCP Oilphase-OBR 31 Job #: 200400350 I Client: BP Field: Prudhoe Bay Schlumberler I Well: S-213A Sand: OBb I Table 17: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.09) Sample#: 1.09; CSB 7690-QA; OBb Sand; MD = 6247 ft; TVD = 5151 ft; TVDSS = -5090 ft Component MW Flashed Gas Flashed liquid Monophasic Fluid I (gjmole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 2.40 1.06 0.00 0.00 0.10 0.40 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 3.06 2.13 0.00 0.00 0.12 0.80 I Methane 16.04 nOD 87.65 0.00 0.00 2.88 32.98 Ethane 30.07 no 5.00 0.00 0.00 0.31 1.88 Propane 44.10 1.47 0.65 0.01 0.08 0.07 0.29 I I - Butane 58.12 1.26 0.42 0.01 0.06 0.06 0.19 N - Butane 58.12 1.98 0.66 0.03 0.15 0.11 0.34 I - Pentane 12.15 1.84 0.50 0.09 0.33 0.16 0.40 I N - Pentane 12.15 2.12 0.57 0.14 0.54 0.22 0.55 C6 84.00 2.65 0.62 0.60 2.02 0.68 1.49 M-C-Pentane 84.16 0.59 0.14 0.22 0.74 0.23 0.51 Benzene 78.11 0.01 0.00 0.01 0.02 0.01 0.02 I Cyclohexane 84.16 0.37 0.09 0.27 0.90 0.27 0.59 C7 96.00 1.03 0.21 1.08 3.19 1.08 2.07 M-C-Hexane 98.19 0.48 0.10 0.71 2.03 0.70 1.30 I Toluene 92.14 0.14 0.03 0.06 0.20 0.07 0.13 C8 107.00 0.49 0.09 1.83 4.82 1.77 3.04 E-Benzene 106.17 0.01 0.00 0.07 0.20 0.07 0.12 I MjP-Xylene 106.17 0.03 0.01 0.15 0.41 0.15 0.26 O-Xylene 106.17 0.01 0.00 0.09 0.25 0.09 0.15 C9 121.00 0.29 0.05 2.14 4.99 2.06 3.13 C10 134.00 0.05 0.01 2.89 6.09 2.77 3.80 I C11 147.00 0.01 0,00 2.67 5.13 2.56 3.20 C12 161.00 0.00 0.00 2.96 5.20 2.84 3.24 C13 175.00 0.00 0.00 3.18 5.14 3.06 3.21 I C14 190.00 0.00 0.00 3.40 5.05 3.26 3.15 C15 206.00 0.00 0.00 3.32 4.56 3.19 2.84 C16 222.00 3.09 3.93 2.96 2.45 I C17 237.00 2.74 3.27 2.63 2.04 C18 251.00 3.14 3.54 3.02 2.21 C19 263.00 2.76 2.96 2.65 1.85 I C20 275.00 2.66 2.73 2.55 1.70 C21 291.00 2.64 2.57 2.53 1.60 C22 300.00 2.25 2.12 2.16 1.32 C23 312.00 2.28 2.06 2.18 1.29 I C24 324.00 2.04 1.78 1.96 1.11 C25 337.00 2.32 1.95 2.23 1.21 C26 349.00 1.62 1.31 1.55 0.82 I C27 360.00 1.87 1.47 1.79 0.91 C28 312.00 1.87 1.42 1.80 0.89 C29 382.00 1.87 1.38 1.79 0.86 I C30+ 750.00 40.95 15.43 39.31 9.63 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 19.53 282.67 183.68 MOLE RATIO 0.3762 0.6238 I WCP Oilphase-DBR 32 Job If.: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBb ScblumberRer Properties Table 18: Calculated Fluid Properties Sample#: 1.09; CSB 7690-QA; OBb Sand; MD = 6247 ft; TVD = 5151 ft; TVDSS = -5090 ft Flashed Gas Flashed liquid Monophasic Fluid Cn+ Composition Mass % Mole% Mass % Mole % Mass % Mole% C7+ 3.52 0.72 99.12 96.83 95.30 60.67 C12+ 0.00 0.00 86.94 67.87 83.46 42.34 C2D+ 62.35 34.21 59.85 21.34 C30+ 40.95 15.43 39.31 963 Molar Mass C7+ 95.99 289.38 288.52 C12+ 362.10 362.10 C20+ 51515 515.15 C30+ 750.00 750.00 Density C7+ 0.9206 C12+ 0.9468 0.9468 C20+ 0.9993 0.9993 C30+ 1.0725 1.0725 FI uid at 60°F 0.9172 Gas Gravity (Air = 1) 0.674 Dry Gross Heat Content (BTU/scf) I 1,137 Wet Gross Heat Content (BTU/scf) 1,117 OBM Contamination level (wt%) ISTO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 284.97 282.67 I 750.00 I Density (g/cm3) 0.917 1.072 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 260 I STO Density (g/cm3) 0.9172 STO API Gravity 22.8 OBM Density (g/cm3! @60°F WCP Oilphase-DBR 33 Job #: 200400350 .1 I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay aBb Figure 13: Stock Tank Oil Chromatogram (Sample 1.09) Sample#: 1.09; CSB 7690-QA; OBb Sand; MD = 6247 ft; TVD = 5151 ft; TVDSS -5090 ft 700 - 600 - 500 - (D 400- Ü I 0 U ), 300 - u ~ 200 - 100 - I I I I I 10 20 30 40 50 min Figure 14: k-Plotfor Equilibrium Check (Sample 1.1)9) Sample#: 1.09; CSB 7690-QA; OBb Sand; MD = 6247 ft; TVD = 5151 ft; TVDSS = -5090 ft 2.50 2.00 . nC4 1.50 . 100 0.50 . C6 0.00 . C7 -"--.-.- -0.50 . C8 -~~~~~._. -1.00 . C9 -1.50 . Cl0 -2.00 -300 -2.00 -100 000 F 100 2.00 300 WCP Oilphase-DBR 34 Job #: 200400350 I Client: BP Field: Prudhoe Bay Schlumb8PI8P I Well: S-213A Sand: OA-Lower I Table 19: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.10) Sample#: 1.10; CSB 7761-0A; OA-Lower Sand; MD = 6059 ft; TVD = 5084 ft; TVDSS = -5022 ft Component MW Flashed Gas Flashed liquid Monophasic Fluid I (g/mole) wr% MOLE % wr% MOLE % wr% MOLE % Carbon Dioxide 44.01 2.47 1.12 0.00 0.00 0.08 0.39 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 6.80 4.86 0.00 0.00 0.22 1.68 I Methane 16.04 68.37 85.40 0.00 0.00 2.26 29.48 Ethane 30.07 5.58 3.72 0.00 0.00 0.18 1.28 Propane 44.10 1.78 0.81 0.01 0.09 0.07 0.34 I I - Butane 58.12 1.52 0.52 0.02 0.08 0.07 0.23 N - Butane 58.12 2.75 0.95 0.04 0.22 0.13 0.47 I - Pentane 72.15 1.93 0.54 0.08 0.32 0.14 0.40 I N - Pentane 72.15 2.19 0.61 0.12 0.51 0.19 0.55 C6 84.00 2.64 0.63 0.44 1.62 0.51 1.28 M-C-Pentane 84.16 0.80 0.19 0.21 0.78 0.23 0.57 I Benzene 78.11 0.02 0.01 0.01 0.02 0.01 0.02 Cyclohexane 84.16 0.48 0.12 0.25 0.93 0.26 0.65 C7 96.00 1.03 0.22 0.76 2.44 0.77 1.67 M-C-Hexane 98.19 0.56 0.11 0.57 1.79 0.57 1.21 I T 01 uene 92.14 0.07 0.02 0.08 0.26 0.08 0.18 C8 1 07. 00 0.56 0.11 1.27 3.67 1.25 2.44 E-Benzene 106.17 0.02 0.00 0.07 0.21 0.D7 0.14 I M/P-Xylene 106.17 0.05 0.01 0.17 0.49 0.17 0.33 a-Xylene 106.17 0.01 0.00 0.09 0.27 0.09 0.18 C9 121.00 0.30 0.05 1.46 3.73 1.42 2.46 C10 134.00 0.04 0.01 2.14 4.92 2.07 3.22 I C11 147.00 0.01 0.00 2.04 4.28 1.97 2.81 C12 161.00 0.00 0.00 2.51 4.81 2.43 3.15 C13 175.00 0.00 0.00 2.88 5.09 2.79 3.33 I C14 190.00 0.00 0.00 3.14 5.10 3.03 3.34 C15 206.00 0.00 0.00 3.12 4.68 3.02 3.06 C16 222.00 2.96 4.11 2.86 2.69 I C17 237.00 3.07 4.00 2.97 2.62 C18 251.00 2.76 3.39 2.66 2.22 C19 263.00 2.63 3.09 2.54 2.02 I C20 275.00 2.51 2.82 2.43 1.85 C21 291.00 2.54 2.69 2.45 1.76 C22 300.00 2.34 2.41 2.26 1.58 C23 312.00 2.12 2.10 2.05 1.38 I C24 324.00 2.09 2.00 2.02 1.31 C25 337.00 1.96 1.80 1.90 1.18 C26 349.00 1.90 1.68 1.84 1.10 I C27 360.00 1.84 1.58 1.78 1.03 C28 372.00 1.66 1.37 1.60 0.90 C29 382.00 2.02 1.64 1.96 1.07 I C30+ 750.00 46.14 19.00 44.61 12.44 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 20.04 308.85 209.16 MOLE RATIO 0.3452 0.6548 I WCP Oilphase-DBR 35 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OA-Lower Scblumberger Table 20: Calculated Fluid Properties Sample#: 1.10; CSB 7761-QA; OA-Lower Sand; MD = 6059 ft; TVD = 5084 ft; TVDSS = -5022 ft Properties Flashed Gas Flashed liquid Monophasic Fluid Cn+ Composition Mass % Mole% Mass % Mole% Mass % Mole % C7+ 3.97 0.83 99.29 97.15 96.14 63. 90 C12+ 0.00 0.00 90.18 73.36 87.20 48.04 C20+ 67.12 39.08 64.90 25.59 C30+ 46.14 19.00 44.61 12.44 Molar Mass C7+ 95.24 31568 314.68 C12+ 379.69 379.69 C20+ 530.41 530.41 C30+ 750.00 750.00 Density C7+ 0.9388 C12+ 0.9599 0.9599 C20+ 1.0113 1.0113 C30+ 1. 0820 1.0820 Fluid at 60°F 0.9357 Gas Gravity (Air = 1! 0.692 Dry Gross Heat Content (BTU/scf) I 1,116 Wet Gross Heat Content (BTU/scf) 1,097 OBM Contamination level (wt%) ISTO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 310.61 308.85 I 750.00 I Density (g/cm3) 0.936 1.082 Single Stage Flash Data Original STO De-Contaminated GOR (scf!stb! 212 I STO Density (g/cm3) 0.9357 STO API Gravity 19.7 OBM Density (g/cm3) @60°F WCP Oilphase-DBR 36 Job #: 200400350 I I I I .1 I I I I I .il Client: Well: BP S-213A Field: Sand: Prudhoe Bay OA-Lower Figure 15: Stock Tank Oil Chromatogram (Sample 1.10) Sample#: 1.10; CSB 7761-QA; OA-Lower Sand; MD = 6059 ft; TVD 5084 ft; TVDSS = -5022 ft rlD1 ~ ~ 700 - ¡;¡ I 600 - 500 - 400- 300 - 200 - 100- I 10 I 20 I 30 I 40 I 50 min Figure 16: k-Plot for Equilibrium Check (Sample 1.10) Sample#: 1.10; CSB 7761-QA; OA-Lower Sand; MD = 6059 ft; TVD = 5084 ft; TVDSS = -5022 ft 250 2.00 .. I I I I I I I 1.50 1.00 .. C6 0.50 .. C7 000 . C8 -0.50 . C9 -1.00 -1.50 -200 -300 . C10 -2.00 -100 000 F 1.00 200 3.00 WCP Oilphase-OBR 37 Job #: 200400350 I CI ¡ent: BP Field: Prudhoe Bay Scblumberger I Well: S-213A Sand: Me I Table 21: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.11) Sample#: 1.11; CSB 7725-0A; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 5.92 2.27 0.00 0.00 0.15 0.92 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.45 0.27 0.00 0.00 0.01 0.11 Methane 16.04 92.29 97.04 0.00 0.00 2.27 39.47 Ethane 30.07 0.35 0.19 0.00 0.00 0.01 0.08 Propane 44.10 0.04 0.01 0.00 0.01 0.00 0.01 I I - Butane 58.12 0.03 0.01 0.00 0.00 0.00 0.01 N - Butane 58.12 0.05 0.02 0.00 0.00 0.00 0.01 I - Pentane 72.15 0.03 0.01 0.00 0.01 0.00 0.01 I N - Pentane 72.15 0.51 0.12 0.02 0.10 0.03 0.11 C6 84.00 0.18 0.04 0.04 0.22 0.04 0.14 M-C-Pentane 84.16 0.02 0.00 0.00 0.02 0.00 0.01 I Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.01 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.02 0.00 0.03 0.12 0.D3 0.07 M-C-Hexane 98.19 0.01 0.00 0.00 0.00 0.00 0.00 I Toluene 92.14 0.06 0.01 0.02 0.09 0.02 0.06 C8 107.00 0.02 0.00 0.01 0.04 0.01 0.02 E-Benzene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 I M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 a-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.00 C9 121.00 0.01 0.00 0.04 0.17 0.04 0.10 I Cl0 134.00 0.00 0.00 0.23 0.80 0.23 0.47 Cll 147.00 0.00 0.00 0.44 1.37 0.43 0.81 C12 161.00 0.00 0.00 0.80 2.26 0.78 1.34 C13 175.00 0.00 0.00 1.06 2.77 1.03 1.64 I C14 190.00 0.00 0.00 1.46 3.52 1.42 2.09 C15 206.00 0.00 0.00 1.84 4.08 1.79 2.42 C16 222.00 1.96 4.05 1.91 2.40 I C17 237. 00 2.06 3.99 2.01 2.37 C18 251.00 2.30 4.20 2.25 2.49 C19 263.00 2.32 4.04 2.27 2.40 I C20 275.00 2.35 3.92 2.30 2.33 C21 291.00 2.28 3.58 2.22 2.13 C22 300.00 2.06 3.14 2.01 1.86 C23 312.00 1.92 2.81 1.87 1.67 I C24 324.00 2.12 2.99 2.06 1.77 C25 337.00 1.83 2.49 1.79 1.48 C26 349.00 1.81 2.38 1.77 1.41 I C27 360.00 1.68 2.14 1.64 1.27 C28 372.00 1.88 2.32 1.84 1.38 C29 382.00 1.98 2.38 1.93 1.41 I C30+ 750.00 65.44 39.96 63.83 23.71 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.87 457.91 278.54 MOLE RATIO 0.4067 0.5933 I WCP Oilphase-DBR 38 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Me Scblumb8Pß8P Table 22: Calculated Fluid Properties Sample#: 1.11; CSB 7725-0A; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft Flashed Gas Flashed Liquid Monophasic Fluid Properties Cn+ Composition C7+ C12+ C20+ C30+ Molar Mass C7+ C12+ C20+ C30+ Density C7+ C12+ C20+ C30+ Fluid at 60°F Gas Gravity (Air = 1) Dry Gross Heat Content (BTU/scf) I Wet Gross Heat Content (BTU/sef) OBM Contamination level (wt%) Mass % 0.15 0.00 96.73 0.582 995 977 Mole% 0.03 0.00 Stock Tank Oil Properties at Standard Conditions: Measured Calculated MW I 460.57 457.91 Density (g/em3) 0.972 Single Stage Flash Data GOR (sef/stb) STO Density (g/em3) STO API Gravity OBM Density (g/em3) @60°F WCP Oilphase-DBR Original STO 194 0.9722 14.0 Mass % 99.94 99.16 85.36 65.44 459.22 468.02 573.92 750.00 0.9725 0.9743 0.9997 1.0410 0.9722 C30+ Properties I 750.00 I 1.041 De-Contaminated I 39 Mole% 99.66 97.02 68.10 39.96 ISTO Basis Live Oil Basis Mass % 97.48 96.72 83.26 63.83 Mole % 59.14 57. 56 40.41 23.71 459.16 468.02 573.92 750.00 0.9743 0.9997 1.0410 Job #: 200400350 I il I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Me figure 17: Stock Tank Oil Chromatogram (Sample 1.11) Sample#: 1.11; CSB 7725-QA; Me Sand; MD 5747 ft; TVD = 4920 ft; TVDSS -4858 ft Ii) D C Ii) (I) N Ii) C C C (I) Ii) Ii) ;¡ m:;:, 0 Q 0iÌÚ1 r I- Ü ðJ Ü I I I I I 10 20 30 40 50 min figure HI: k-Plotfor Equilibrium Check (Sample 1.11) Sample#: 1.11; CSB 7725-QA; Me Sand; MD = 5747 ft; TVD 4920 ft; TVDSS -4858 ft 1.80 1.60 ~ iC4 1.40 1.20 ~ nC5 ~ C3 100 . iCS 0.80 0.60 0.40 'lO C6 0.20 0.00 -020 ~ C7 -0.40 -200 -1.50 -100 -050 000 0.50 100 1.50 2.00 2.50 3.00 F I WC? Oilphase-DBR 40 Job #: 200400350 I Client: BP Field: Prudhoe Bay Schlumb8rl8r I Well: S-213A Sand: Mb1 I Table 23: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.12) Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MD = 5531 ft; TVD = 4780 ft; TVDSS = -4718 ft Component MW Flashed Gas Flashed Liquid Monophasic Fluid I (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 3.82 1.44 0.00 0.00 0.10 0.62 Hydrogen SulfidE 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.62 0.37 0.00 0.00 0.02 0.16 I Methane 16.04 94.93 97.99 0.00 0.00 2.39 41.98 Ethane 30.07 0.21 0.12 0.00 0.00 0.01 0.05 Propane 4410 0.03 0.01 0.00 0.03 0.00 0.02 I I - Butane 58.12 0.02 0.01 0.00 0.01 0.00 0.01 N - Butane 58.12 0.03 0.01 0.00 0.01 0.00 0.01 I - Pentane 7215 0.02 0.00 0.00 0.01 0.00 0.01 I N - Pentane 7215 0.12 0.03 0.00 0.02 0.01 0.02 C6 84.00 0.07 0.01 0.04 0.20 0.04 0.12 M-C-Pentane 84.16 0.01 0.00 0.00 0.02 0.00 0.01 Benzene 78.11 0.00 0.00 0.00 0.00 0.00 0.00 I Cyclohexane 84.16 0.00 0.00 0.00 0.01 0.00 0.00 C7 96.00 0.01 0.00 0.03 0.17 0.03 0.10 M-C-Hexane 98.19 0.01 0.00 0.00 0.01 0.00 0.01 I Toluene 92.14 0.10 0.02 0.04 0.23 0.05 0.14 C8 107.00 0.01 0.00 0.01 0.05 0.01 0.03 E-Benzene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 I M/P-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 0.00 a-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.00 C9 121. 00 0.00 0.00 0.04 0.17 0.04 0.10 C10 134.00 0.00 0.00 0.16 0.56 0.15 0.32 I C11 147.00 0.00 0.00 0.31 1.02 0.30 0.58 C12 161.00 0.00 0.00 0.61 1.83 0.60 1.05 C13 175.00 0.00 0.00 0.87 2.39 0.85 1.37 I C14 190.00 0.00 0.00 1.23 3.10 1.19 1.77 C15 206.00 0.00 0.00 1.52 3.54 1.48 2.02 C16 222.00 1.62 3.50 1.58 2.00 I C17 237.00 1.69 3.43 1.65 1.96 C18 251.00 2.03 3.88 1.98 2.22 C19 263. 00 2.02 3.69 1.97 2.11 C20 275.00 2.10 3.67 2.05 2.10 I C21 291.00 2.15 3.55 2.10 2.03 C22 300.00 1.82 2.91 1.77 1.66 C23 312.00 2.03 3.12 1.98 1.79 I C24 324.00 1.87 2.78 1.83 1.59 C25 337.00 1.71 2.44 1.67 1.39 C26 349.00 1.72 2.36 1.67 1.35 I C27 360.00 1.92 2.56 1.87 1.47 C28 37200 1.82 2.35 1.77 1.34 C29 382.00 1.82 2.29 1.77 1.31 I C30+ 750.00 68.80 44.07 67.07 25.19 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.56 480.41 281.70 MOLE RATIO 0.4284 0.5716 I WCP Oilphase-DBR 41 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Mb1 Schlumb8Pg8P Properties Table 24: Calculated Fluid Properties Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MO = 5531 ft; TVO = 4780 ft; TVOSS = -4718 ft Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole % C7+ 0.14 0.02 99.96 99.73 97.44 57.02 C12+ 0.00 0.00 99.34 97.47 96.84 55.71 C20+ 87.76 72.11 85.55 41.22 C30+ 68.80 44.07 67. 07 25.19 Molar Mass C7+ 94.28 481.51 481.44 C12+ 489.66 489.66 C20+ 584.69 584.69 C30+ 750.00 750.00 Density C7+ 0.9799 C12+ 0.9814 0.9814 C20+ 1.0033 1.0033 C30+ 1.0417 1.0417 Fluid at 60°F 0.9797 Gas Gravity (Air = 1) 0.572 Dry Gross Heat Content (BTU/scf) J 998 Wet Gross Heat Content (BTU/scf 980 OBM Contamination level (wt%) ISTO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 482.89 480.41 I 750.00 I Density (g/cm3) 0.980 1.042 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 203 I STO Density (g/cm3) 0.9797 STO API Gravity 12.9 OBM Density (g/cm3) @60°F WCP Oilphase-DBR 42 Job #: 200400350 Client: Well: BP S-213A Field: Sand: Prudhoe Bay Mb1 Figure 19: Stock Tank Oil Chromatogram (Sample 1.12) Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MD = 5531 ft; TVD 4780 ft; TVDSS = -4718 ft FID1 pA. I I 'I I I I 500 - 1100 - 300 - 200 - I 110 I 50 mln Figure 20: k-Plot fOt" Equilibrium Check (Sample 1.12) Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MD 5531 ft; TVD 4780 ft; TVDSS = -4718 ft I I I I I I I I lAO . nC5 1.20 . nC4 100 4Þ iC4 <i 0.80 . CJ .:.:: * IC5 ìS .9 0.60 OAO 020 000 -2.00 -1.50 -1.00 -0.50 000 0.50 1.00 150 2.00 2.50 3.00 F WCP Oilphase-DBR 43 Job #: 200400350 I I I I Client: Well: I I I I I I I I I I I I I I I WCP Oilphase-DBR BP S-213A Field: Sand: Prudhoe Bay OBd Schlumbepgep Table 25: Summary of Results of Sample 1.01 Sample#: 1.01; CSB 7759-0A; OBd Sand; MD = 6824 ft; TVD = 5258 ft; TVDSS = -5196 ft Reservoir Conditions: Pressu re: Temperature: Summary of Fluid Properties: Bubble Point Pressure At Tres Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at GO°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Yiscosity: Compressibillity (Co): pensity: Properties at Saturation Conditions Viscosity: Compressibillity (Co): pensity: Formation Volume Factor Single-stage Flash: Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F 2594 104 2,013 310 STO ° API 24.1 8.0 74 @Pres & Tres 44 pSla of pSI a scf/stb scf/stb scf/stb Gas Gravity (Average) 0.669 cP 10-6/psi g/cc cP 1 06 Ipsi g/cc @Psat & Tres 1.147 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBd Scblumberger PVT Analysis on Sample#: 1.01; CSB 7759-QA; OBd Sand; MD = 6824 ft; TVD = 5258 ft; lVDSS = -5196 ft Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 104°F. These values as a function of selected pressure steps are summarized in Table 26. The liquid phase viscosity values are graphically presented in Figure 21. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 26: Reservoir Fluid Viscosity 104°F (Sample 1.01) Sample#: 1.01; CSB 7759-0A; OBd Sand; MD = 6824 ft; TVD = 5258 ft; TVDSS = -5196 ft Pressure Viscosity @ Tres (psi a} (cP) 1 2 3 4 5 6 7 8 Pi Pb 11 12 13 14 15 16 17 18 STO WCP Oilphase-DBR 9005 8028 7055 6018 5041 4016 3520 3023 2594 2013 1726 1590 1510 1405 1165 748 440 100 14.696 16.0 14.6 13.3 12.1 10.9 9.7 9.1 8.5 8.0 7.4 n 7.9 8.0 8.3 9.0 10.9 13.0 17.2 20.6 45 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBd Schlumbe.rger Figure 21: Reservoir Fluid Viscosity 104°F (Sample 1.01) Sample#: 1.01; CSB 7759-QA; OBd Sand; MD = 6824 ft; TVD = 5258 ft TVDSS = -5196 ft 25 o 20 ii:" E ~ .¡¡¡ 15 CI Co) UI :;: 10 5 o 6000 8000 10000 2000 4000 Pressure (psia) WCP Oilphase-DBR 46 Job #: 200400350 I I Client: Well: I I I I I I I I I I I I I I I I I WCP Oilphase-DBR BP S-213A Field: Sand: Prudhoe Bay OBa ScblumblPllP Table 27: Summary of Results of Sample 1.04 Sample#: 1.04; CSB 7476-MA; DBa Sand; MD = 6177 ft; TVD = 5130 ft; TVDSS = -5068 ft Reservoir Conditions: Pressu re: 2523 101 Temperature: Summary of Fluid Properties: Bubble Point Pressure At Tres Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at 60°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: Compressìbillity (Co): Density: Properties at Saturation Conditions Viscosity: Compressi bi II ity (Co): Density: Formation Volume Factor Single-stage Flash: Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F 1,987 234 STO °API 18.8 31.4 29.1 @Pres & Tres 47 psia of pSla scf/stb scf/stb scf/stb Gas Gravity (Average) 0.636 cP W%si glee CP 1O-6/psi glee @Psat & Tres 1.102 Job #: 200400350 I I I I I I I I I I I I I I I I I I I CI ient: Well: BP S-213A Field: Sand: Prudhoe Bay OBa Schlumberler PVT Analysis on Sample#: 1.04; CSB 7476-MA; DBa Sand; MO = 6177 It; TVO = 5130 ft; TVOSS = -5068 ft Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 101°F. These values as a function of selected pressure steps are summarized in Table 28. The liquid phase viscosity values are graphically presented in Figure 22. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint Table 28: Reservoir Fluid Viscosity 101°F (Sample 1.04) Sample#: 1.04; CSB 7476-MA; aBa Sand; MD = 6177 ft; TVD = 5130 ft; TVDSS = -5068 ft Pressure Viscosity @ Tres (psi a} (cP) 1 2 3 4 5 6 7 8 Pi Pb 11 12 13 14 15 16 17 18 STO WCP Oilphase-DBR 8920 8016 7022 6023 5028 4024 3520 3027 2523 1987 1833 1746 1645 1548 1426 1320 1141 549 14.696 69.3 62.6 55.9 49.6 43.9 38.5 36.0 33.7 31.4 29.1 31.8 33.0 34.4 36.1 38.3 40.5 44.8 67.2 105.1 48 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: 120 o 100 80 ã: E. i:' '¡¡¡ CI u en :;; 60 WCP Oilphase-DBR BP S-213A Field: Sand: Prudhoe Bay DBa Schlumbøpger Figure 22: Reservoir Fluid Viscosity 101°F (Sample 1.04) Sample#: 1.04; CSB 7476-MA; OBa Sand; MO == 6177 ft; TVO == 5130 ft; TVOSS == -5068 ft 40 20 o 4000 6000 Pressure (psia) 8000 10000 2000 49 Job #: 200400350 I I I I I I I I I Client: Well: I I I I I I I I I I WCP Oilphase-DBR BP S-213A Field: Sand: Prudhoe Bay OBc Schlumberger Table 29: Summary of Results of Sample 1.08 Sample#: 1.08; CSB 7755-0A; OBc Sand; MO = 6403 ft; TVO = 5190 ft; TVOSS = -5128 ft ReselVoir Conditions: Pressure: Temperature: Summary of Fluid Properties: Bubble Point Pressure At Tres Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at GO°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at ReselVoir Conditions Vi scosity: Compressibillity (Co): Density: Properties at Saturation Conditions Vi scosity: Compressibillity (Co): Density: Formation Volume Factor Single-stage Flash: Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F 2558 103 1,947 291 STO °API 24.5 11.9 11.0 @Pres & Tres 50 pSla of pSI a scf/stb scf Istb scf/stb Gas Gravity (Average) 0.676 cP W6¡psi g/cc cP 106¡psi g/cc @Psat & Tres 1.137 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBc Schlulbepgep PVT Analysis on Sample#: 1.08; CSB 7755-QA; OBc Sand; MD = 6403 ft; TVD = 5190ft; TVDSS = -5128 ft Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 103°F. These values as a function of selected pressure steps are summarized in Table 30. The liquid phase viscosity values are graphically presented in Figure 23. As seen in the figures and as expected. the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 30: Reservoir Fluid Viscosity 103°F (Sample 1.08) Sample#: 1.08; CSB 7755-QA; OBc Sand; MD = 6403 ft; TVD = 5190 ft; TVDSS = -5128 ft Pressure Viscosity @ Tres (psial (cPI 1 2 3 4 5 6 Pi 8 Pb 10 11 12 13 14 15 16 STO WCP Oilphase-DBR 8014 7015 6008 5012 4020 3026 2558 2124 1947 1787 1438 1316 1143 876 581 117 14.696 20.6 18.9 17.2 15.6 14.1 12.6 11.9 11.3 11.0 11.0 11.1 11.2 11.4 119 13.9 18.7 20.9 51 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBc Schlumberger Figure 23: Reservoir Fluid Viscosity 103°F (Sample 1.08) Sample#: 1.08; CSB 7755-0A; OBc Sand; MD = 6403 ft; TVD = 5190 ft; TVDSS = -5128 ft 0 20 ~ ~ .ï=' '¡;¡ CI u en :; 15 WCP Oilphase-DBR 25 10 o 2000 4000 6000 Pressure (ps ia) 52 8000 10000 Job #: 200400350 I I I Client: Well: I I I I I I I I I I I I I I I I WCP Oilphase-DBR BP S-213A Field: Sand: Prudhoe Bay OBb Scblumbørgør Table 31: Summary of Results of Sample 1.09 Sample#: 1.09; CSB 7690-0A; OBb Sand; MD = 6247 ft; TVD = 5151 ft; TVDSS = -5090 ft Reservoir Conditions: Pressure: 2542 102 Temperature: Summary of Fluid Properties: Bubble Point Pressure At T res Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at 60°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: Compressibillity (Co): Density: Properties at Saturation Conditions Viscosity: 11.62 Compressibillity (Co): Density: Formation Volume Factor 1,884 260 STO °API 22.8 12.72 @Pres & Tres Single-stage Flash: Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F 53 psia of psia scf/stb scf/stb scf/stb Gas Gravity (Average) 0.674 cP 1O-6/psi g/cc CP 1O-6/psi g/cc @Psat & Tres 1.113 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBb Scblumb8PI8P PVT Analysis on Sample#: 1.09; CSB 7690-0A; OBb Sand; MO = 6247 ft; TVO = 5151 ft; TVOSS = -5090 ft Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 102°F. These values as a function of selected pressure steps are summarized in Table 32. The liquid phase viscosity values are graphically presented in Figure 24. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 32: Reservoir Fluid Viscosity 102°F (Sample 1.09) Sample#: 1.09; CSB 7690-QA; OBb Sand; MD = 6247 ft; TVD = 5151 ft; TVDSS = -5090 ft Pressure Viscosity @ Tres (psia) (cP) 1 2 3 4 5 6 7 8 Pi Pb 11 12 13 14 15 16 17 18 19 STO WCP Oilphase-DBR 9021 8053 7032 6038 5042 4024 3526 3024 2542 1884 1639 1460 1285 1084 962 844 667 505 276 14.696 25.3 22.9 20.7 18.8 17.0 152 14.4 13.5 12.7 11,6 11.8 12.1 12.7 13.6 14.1 14.8 16.0 17.3 20.0 32.3 54 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OBb Schlumberger Figure 24: Reservoir Fluid Viscosity 102°F (Sample 1.09) Sample#: 1.09; CSB 7690-QA; OBb Sand; MD = 6247 ft; TVO = 5151 ft; TVOSS = -5090 ft 35 o 30 25 õ: E. ~ .¡;; 0 U III :> 20 15 10 o 6000 8000 10000 2000 4000 Pressure (psia) WCP Oilphase-DBR 55 Job #: 200400350 I I I I I I I I I I I I Client: Well: I I I I I I I BP S-213A Field: Sand: Prudhoe Bay OA-Lower Scblumbepgep Table 33: Summary of Results of Sample 1.10 Sample#: 1.10; CSB 7761-0A; OA-Lower Sand; MD = 6059 ft; TVD = 5084 ft; TVDSS = -5022 ft Reservoir Conditions: Pressu re: Temperature: Summary of Fluid Properties: Bubble Point Pressure AtTres Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at 60°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: Compressibillity (Co): Density: Properties at Saturation Conditions Vi scosity: Compressibillity (Co): Density: Formation Volume Factor Si ngle-stage Flash: Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psi a and 60°F 2482 101 1,836 212 STO °API 19.7 28.2 26.0 @Pres & Tres WCP Oilphase-DBR 56 psi a of pSla scf/stb scf/stb scf/stb Gas Gravity (Average) 0.692 cP 10B¡psi g/cc cP 10-6/psi g/cc @Psat & Tres 1.091 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay DA-Lower Scblumbepgep PVT Analysis on Sample#: 1.10; CSB 7761-0A; OA-Lower Sand; MD = 6059 ft; TVD = 5084 It TVDSS = -5022 ft Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 101°F. These values as a function of selected pressure steps are summarized in Table 34. The liquid phase viscosity values are graphically presented in Figure 25. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 34: Reservoir Fluid Viscosity 101°F (Sample 1.10) Sample#: 1.10; CSB 7761-QA; OA-Lower Sand; MO = 6059 ft; TVO = 5084 ft; TVOSS = -5022 ft Pressure Viscosity @ Tres (psia) (cP) 1 2 3 4 5 6 7 8 9 10 Pi 11 Pb 12 13 14 15 16 17 STD WCP Oilphase-DBR 9017 8026 7027 6035 5079 4520 4015 3517 3040 2517 2482 2030 1836 1705 1511 1372 1167 1059 703 14.696 59.0 52.4 46.6 41.2 36.8 34.4 32.1 29.9 28.2 26.4 26.3 24.7 24.0 25.1 270 28.8 31.4 33.3 42.8 75.7 57 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay OA-Lower Scblumbepger Figure 25: Reservoir Fluid Viscosity 101°F (Sample 1.10) Sample#: 1.10; CSB 7761-0A; OA-Lower Sand; MD = 6059 ft; TVD = 5084 ft; TVDSS = -5022 ft 80 ! 70 60 ëL E. ~ '¡¡¡ 50 CI .... en ::;: 40 30 20 o WCP Oilphase-DBR 2000 4000 6000 10000 8000 Pressure (psia) 58 Job #: 200400350 I I Client: Well: I I I I I I I I I I I I I I I I I WCP Oilphase-DBR BP S-213A Field: Sand: Prudhoe Bay Scblumbepgep Table 35: Summary of Results of Sample 1.11 Sample#: 1.11; CSB 7725-0A; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft Reservoir Conditions: Pressure: Temperature: Summary of Fluid Properties: Bubble Point Pressure AtTres Gas-Oil Ratio Si ngle-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at GO°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: Compressibillity (Co): Density: Properties at Saturation Conditions Viscosity: Compressibillity (Co): Density: Formation Volume Factor Single-stage Flash: Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psi a and 60°F 2427 98 psi a of 1,818 psia 194 186 scf/stb scf/stb scf/stb Gas Gravity (Average) 0.582 0.578 STO °API 14.0 14.2 294.4 5.2 0.939 CP 1O-6/psi g/cc 259.8 5.7 0.936 cP 106¡psi g/cc @Psat & Tres 1.065 1.063 @Pres & Tres 1.061 1. 059 59 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Schlumberler PVT Analysis on Sample#: 1.11; CSB 7725-0A; Me Sand; MD = 5747 ft; TVD = 4920ft; TVDSS = -4858ft Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 98.0°F and at a pressure of 9.015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 36. The pressure-volume (P-V) plots of the CCE data are presented in Figure 26. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid. the bubblepoint was determined to be 1.818 psia at the reservoir temperature of 98.0 OF. Also. calculated relative volume and oil compressibility is presented in Table 36. As seen in the table. the compressibility of this oil is 5.7 x 10e-6 1/psia at the saturation pressure. Table 36: Constant Composition Expansion at 98.0°F (Sample 1.11) Sample#: 1.11; CSB 7725-0A; Mc Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VINsat) (VINtotal) (g/cm3) (10·6/psia) 1 9015 0.9763 0.959 1.7 2 8015 0.9781 0.957 2.0 3 7015 0.9803 0.955 2.4 4 5015 0.9859 0.950 3.4 5 3015 0.9938 0.942 4.7 6 2715 0.9953 0.941 4.9 Pi 2427 0.9967 0.939 5.2 8 2115 0.9984 0.938 5.4 Pb 1818 1.0000 100.0 100.0 0.936 5.7 10 1629 1.0129 99.6 98.3 9.0 11 1549 1.0203 99.5 97.5 8.6 12 1487 1.0269 99.3 96.7 8.3 13 1370 1.0421 99.2 95.2 7.8 14 1220 1.0713 98.8 92.3 6.9 15 1064 1.1142 98.5 88.4 6.2 16 862 1.1960 98.1 82.0 5.7 17 674 1 .3237 97.7 73.8 5.2 18 515 1.5182 97.4 64.1 4.9 19 395 1.7774 97.2 54.7 4.6 20 340 1.9726 97.0 49.2 4.5 WCP Oilphase-DBR 60 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: WCP Oil~lhase-DBR BP S-213A Field: Sand: Prudhoe Bay Schlumbepgep Figure 26: Constant Composition Expansion at 98.0°F - Relative Volume Sample#: 1.11; CSB 7725-0A; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft 2.0 .0 1.8 o 1.6~~ :ë a.. @) ~ ~ ~ 14 = Õ > CD .æ: 1; ãi a:: 1.2 1.0 0.8 o o Q 2000 -~------~ o 0----0---0 4000 6000 8000 10000 Pressure (psia) 61 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Schlumb8rl8r Differential Vaporization Results of the differential vaporization test are presented in Tables 37 through 39 and graphically presented in Figures 27 through 28. O¡f Phase Properties The oil properties such as oil formation volume factor. oil density and solution Gas-ail-ratios are summarized in Table 37. The oil formation volume factor is presented as afunction of differential pressures in Figure 27. As expected, the oil formation volume factor increases with decreasing pressure until the bubblepoint. and subsequently, decreases with decreasing pressure. Solution GaR shows a decreasing trend with decreasing pressures (Figure 27). Oil densities were measured at the initial and the saturation pressure conditions and the intermediate values are calculated based on known mass and measured volume. The liquid density is measured to be 0.936 g/cc at the bubblepoint pressure (Table 37). The liquid density decreases with decreasing pressure until the bubblepoint. and increases with further decrease in pressure (Figure 27). Gas Phase Properties The calculated differentially vaporized gas properties are summarized in Table 38 and graphically presented in Figures 28. As seen in the table and figures. gas volume factor shows an increasing trend with a decrease in pressure. The Gas deviation factor and gas relative density values of the liberated gas tend to decrease slightly and then increase with a decreasing function of pressure. However, the gas viscosity that is calculated at the differential pressure steps from gas composition decrease with decrease in pressure as seen in Figure 28. Compositions Compositions of the differentially liberated gas at each differential pressure step are presented in Table 39 along with calculated molecular weights. As seen in the table, and as expected, the concentrations of the heavier components in the liberated gas decreases with a decrease in pressure due to the inability of the gas to supercritically extract heavy ends at lower pressures. However. below 1818.40893352586 psia, the concentration of intermediate/heavy components (>C3) of the liberated gas increases as their partial pressures become significant. Composition of the residual oil obtained from the differential vaporization is presented in Table 39. The API Gravity of the residual oil is measured to be 14.2. WCP Oilphase-DBR 62 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: WCP Oilphase-DBR BP S-213A Field: Sand: Prudhoe Bay Schlumbepgep Table 37: Differential Liberation Test 90°F - Liquid Properties Sample#: 1.11; CSB 7725-0A; Me Sand; MO = 5747 ft; TVO = 4920 ft; TVOSS = -4858 ft Pressure (psia) 1 9015 2 8015 3 7015 4 5015 5 3015 6 2715 Pi 2427 8 2115 Pb 1818 1 1215 2 615 3 315 STD 14.696 Residual oil density at 60 OF (glee) API Gravity Oil Volume Factor Bo (bbl/stb) 1.037 1.039 1.042 1. 048 1.056 1.057 1.059 1.061 1.063 1.045 1.027 1.019 1. 006 0.971 14.2 Solution Gas GOR Rs (scf/stb) 186 186 186 186 186 186 186 186 186 126 69 43 o 63 Calculated Liquid Density (g/cm3) 0.959 0.957 0.955 0.949 0.942 0.940 0.939 0.937 0.936 0.945 0.954 0.958 0.965 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay SchlumbePlep Figure 27: Differential Liberation 98°F - Liquid Properties Sampl e#: 1.11; CSB 7725-0A; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft 1.07 1.06 ~ .CI ~ :¡; 1.05 ~ C) ~ 1.04 S u ,f 1.03 CD E = ~ 1.02 Õ 1.01 ~ -()- --0 1.00 o ~ '¡j 'È 150.0 .!!!. ~ III cc: § 100.0 en III c.:I = C) ''¡ 50.0- Õ en 2000 4000 6000 8000 10000 0 0 Ò 0 -~-~ --~ --,~~ 200.0 -_.,~------~'-~- 0.0 o 2000 4000 6000 8000 10000 0.98 M !3 0.96 ~ ¡:- '¡¡¡ = CD Q 'C 'g. 0.94 :::¡ 0.92 o 2000 4000 6000 8000 10000 Pressure (psia) WCP Oilphase-DBR 64 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Scblumb8Pgøp Table 38: Differential liberation Test 98°F - Gas Properties Sample#: 1.11; CSB 7725-QA; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft Pressure (1lGas FVF Z (2)Predicted Vapor (37otal FVF Bg Factor Gas Gravity Bt (psia) (ft3/mm 113) Viscosity (cP) (air=1) (bbl/stb) Pb 1818 1.063 1 1215 11266 0.868 0.0136 0.570 1.164 2 615 23727 0.925 0.0118 0.572 1.519 3 315 48094 0.960 0.0109 0.577 2.237 STO 14.696 1072773 1. 000 0.0100 0.597 36.448 1. Bg = Reservoir gas at P & T per 1 million equivalent cubic ft. gas at 14.696 psia & 60°F 2. Lee & Gonzalez Correlation 3. Bt = Oil FVF + [(T otalliberated gas)*Gas FVF]*1 0.6 WCP Oilphase-DBR 65 Job #: 200400350 I Client: BP Field: Prudhoe Bay SchlumbePlep I Well: S-213A Sand: I Figure 28: Differential Liberation 98°F - Gas Properties Sample#: 1.11; CSB 7725-0A; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft 1.1 I & 1.0 0- I š -0 u III .... (>. = .g 0.9 ~--,----- -~~-~._~-~ III () I .¡;; G) CI /II ~ 0.8 -- I 0.7 0 200 400 600 800 1000 1200 1400 I 0.61 I 0.60 I ! :§. 0.59 ------~_. .i:' '¡;; III I ~ 0.58 III c:I 0.57 ,0 0 I 0.56 I 0 200 400 600 800 1000 1200 1400 0.0140 I 0.0130 ~ u I -; 0.0120 .¡;¡ 0 U /II :: 0.011 0 I III c:I 0.0100 I 0.0090 0 200 400 600 800 1000 1200 1400 I Pressure (psia) WCP Oilphase-DBR 66 Job #: 200400350 I I I Client: BP Field: Prudhoe Bay Schlumbepgep Well: S-213A Sand: I Table 39: Differential liberation Test 98°F - Vapor & STO Composition (mol %) Sample#: 1.11; CSB 7725-0A; Me Sand; MO = 5747 ft; TVO = 4920 ft; TVOSS = -4858 ft Component MW Mol % at Specified Pressure (psial Mol % at 14.696 psia I I (g/mol) 1215 615 315 Vapor Residual Liquid Carbon Dioxide 44.01 1.36 1.63 2.16 3.93 0.00 Hydrogen Sulfide 34.08 0.00 0.00 0.00 0.00 0.00 I Nitrogen 28.01 0.48 0.29 0.17 0.02 0.00 Methane 16.04 98.06 97.96 97.50 95.53 0.00 Ethane 30.07 0.08 0.09 0.14 0.34 0.00 I Propane 44.10 0.00 0.00 0.01 0.05 0.05 I - Butane 58.12 0.00 0.00 0.00 0.01 0.01 N - Butane 58.12 0.00 0.00 0.00 0.01 0.01 I - Pentane 72.15 0.00 0.00 0.00 0.00 0.00 I N - Pentane 72.15 0.01 0.01 0.01 0.05 0.04 C6 84.00 0.01 0.01 0.01 0.03 0.16 M-C-Pentane 84.16 0.00 0.00 0.00 0.00 0.02 I Benzene 78.11 0.00 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.00 0.00 0.00 0.00 0.06 I M-C-Hexane 98.19 0.00 0.00 0.00 0.00 0.00 Toluene 92.14 0.00 0.01 0.01 0.03 0.53 C8 107.00 0.00 0.00 0.00 0.00 0.01 E-Benzene 106.17 0.00 0.00 0.00 0.00 0.00 I MjP-Xylene 106.17 0.00 0.00 0.00 0.00 0.00 O-Xylene 106.17 0.00 0.00 0.00 0.00 0.01 C9 121.00 0.00 0.00 0.00 0.00 0.15 I C10 134.00 0.00 0.00 0.00 0.00 0.76 C11 147.00 0.00 0.00 0.00 0.00 1.50 C12 161.00 0.00 0.00 0.00 0.00 2.24 I C13 175.00 0.00 0.00 0.00 0.00 3.00 C14 190.00 0.00 0.00 0.00 0.00 3.47 C15 206.00 0.00 0.00 0.00 0.00 4.10 C16 222.00 0.00 0.00 0.00 0.00 4.01 I C17 237.00 0.00 0.00 0.00 0.00 3.98 C18 251.00 0.00 0.00 0.00 0.00 4.17 C19 263.00 0.00 0.00 0.00 0.00 3.80 I C20 275.00 0.00 0.00 0.00 0.00 4.01 C21 291.00 0.00 0.00 0.00 0.00 3.31 C22 300.00 0.00 0.00 0.00 0.00 3.34 I C23 312.00 0.00 0.00 0.00 0.00 2.77 C24 324.00 0.00 0.00 0.00 0.00 2.91 C25 337.00 0.00 0.00 0.00 0.00 2.40 C26 349.00 0.00 0.00 0.00 0.00 2.52 I C27 360.00 0.00 0.00 0.00 0.00 2.26 C28 372.00 0.00 0.00 0.00 0.00 2.12 C29 382.00 0.00 0.00 0.00 0.00 2.65 I C30+ 750.00 0.00 0.00 0.00 0.00 39.61 Total 100.00 100.00 100.00 100.00 100.00 Calculated MW 16.51 16.57 16.71 17.29 455.7 5 I Relative Density (air=1) 0.570 0:572 0.577 0.597 Dry Gross Heat Content (BTUjscf) 995 994 991 980 I WCP Oilphase-DBR 67 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay SchlumblPglP Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 98°F. These values as a function of selected pressure steps are summarized in Table 40. The liquid phase viscosity values are graphically presented in Figure 29. As seen in the figures and as expected. the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 40: Reservoir Fluid Viscosity 98°F Sample#: 1.11; CSB 7725-0A; Mc Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft Pressure Viscosity @ Tres {psi a} {cP} 1 2 3 4 5 6 7 Pi 9 Pb 10 11 12 13 14 15 STO WCP Oilphase-DBR 8057 7024 6022 5033 4037 3526 3024 2427 2109 1818 1569 1391 1226 1106 971 809 14.696 763.5 657.6 563.3 478.4 401.3 365.0 331.5 294.4 275.9 259.8 281.2 300.3 331.8 364.1 400.0 485.0 1277.0 68 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Schlumbepgep Figure 29: Reservoir Fluid Viscosity 98°F Sample#: 1.11; CSB 7725-QA; Me Sand; MD = 5747 ft; TVD = 4920 ft; TVDSS = -4858 ft 1400 1200 . 1000 ~ ~ ~ 800 "¡;; 0 '" III :;: 600 400 200 o WCP Oilphase-DBR o 2000 4000 6000 Pressure (psia) 69 8000 10000 Job #: 200400350 I I Client: Well: I I I I I I I I I I I I I I I I I BP S-213A Field: Sand: Prudhoe Bay Mb1 Schlumberger Table 41: Summary of Results of Sample 1.12 Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MD = 5531 ft; TVD = 4780 ft; TVDSS = -4718 ft ReselVoir Conditions: Temperature: Summary of Fluid Properties: Bubble Point Pressure At T res Gas-Oil Ratio Single-stage Flash: Total Differential Liberation: Total Separator Flash: Properties at 60°F Single-stage STO: Differential Liberation STO: Separator STO: Properties at ReselVoir Conditions Viscosity: Compressi bi II ity (Co!: Density: Properties at Saturation Conditions Viscosity: Compressibillity (Co!: Density: Formation Volume Factor Single-stage Flash: Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F Pressu re: WCP Oilphase-DBR 2358 95 1)69 203 STO °API 12.9 4.8 0.952 5.0 0.950 @Pres& Tres 1.055 70 psia of psia scf/stb scf/ st b scf/stb Gas Gravity (Average) 0.572 cP 1o-6/psi g/cc cP 10-6¡psi g/cc @Psat & Tres 1.058 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Mb1 Scblumberger PVT Analysis on Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MD = 5531 ft; TVD = 4780 ft; TVDSS = -4718 ft Constant Composition Expansion at Tres The eeE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 95.0°F and at a pressure of 9,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 42. The pressure-volume (P-V) plots of the eeE data are presented in Figure 30. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,769 psia at the reservoir temperature of 95.0 of. Also, calculated relative volume and oil compressibility is presented in Table 42. As seen in the table, the compressibility of this oil is 5.0 x lOe-6 1jpsia at the saturation pressure. Table 42: Constant Composition Expansion at 95.0°F (Sample 1.12) Sample#: 1.12; eSB 7680-QA; Mb1 Sand; MD = 5531 ft; TVD = 4780 ft; TVDSS = -4718 ft Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VlNsat) (VINtotal) (g/cm3) (1 O-G/psi a) 1 9015 0.9727 0.976 2.8 2 8003 0.9756 0.973 3.1 3 7015 0.9787 0.970 3.3 4 6015 0.9820 0.967 3.6 5 5015 0.9857 0.963 3.9 6 4015 0.9897 0.959 4.2 7 3015 0.9941 0.955 4.6 Pi 2358 0.9971 0.952 4.8 8 2015 0.9988 0.951 4.9 Pb 1769 1.0000 100.0 100.0 0.950 5.0 10 1583 1.0078 99.6 98.8 15.0 11 1528 10109 99.5 98.4 14.5 12 1495 1.0128 99.5 98.2 14.3 13 1420 1.0178 99.3 97.6 13.8 14 1302 1.0276 99.1 96.4 130 15 1217 1. 0364 99.0 95.5 12.5 16 1115 1.0498 98.7 94.0 11.8 17 1031 1.0646 98.6 92.6 11.1 18 932 1.0851 98.4 90.7 10.6 19 640 1. 2027 97.9 81.4 8.7 20 485 1 .3408 97.6 72.8 7.8 21 365 1.5643 97.4 62.3 6.8 22 295 1.8058 97.3 53.9 6.2 23 226 2.1962 97.2 44.2 5.7 WCP Oilphase-DBR 71 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Mb1 Schlumbepgep Figure 30: Constant Composition Expansion at 95.0°F - Relative Volume Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MO = 5531 ft; TVO = 4780 ft; TVOSS = -4718 ft 2.4 2.2 -0 2.0 -------~~ ~ 1.8 -0 a.. @) ~ ~ ~ 1.6 - -E - 0 > G) .:ë; IV -¡; cc 1.4 __N______~~___· <) 1.2 1.0 0.8 o 2000 4000 6000 8000 10000 Pressure (psial WCP Oilphase-DBR 72 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: BP S-213A Field: Sand: Prudhoe Bay Mb1 Schlulbepgep Dead Oil Viscosity at Tres During the PVT testing on sample 1.12, we didn't have enough volume for the DV and the viscosity testing. Hence, we only measured the dead oil viscosity, which was 3289 cP at the reservoir temperature of 95°F. Then we blewdown the residual sample inside the cylinder and recovered about 30 cc Stock Tank Liquid (STL). The centrifuged STL had a density of 0.987 glcc at 60°F, which had an API of 11.9. The centrifuged STL also had a water content of 8.5% wt%. Table 43: Dead Oil Viscosity 95°F (Sample 1.12) Sample#: 1.12; CSB 7680-QA; Mb1 Sand; MD = 5531 ft; TVD = 4780 ft; TVDSS = -4718 ft Pressure Viscosity @ Tres {psial {cPI STO 15 3289 WCP Oilphase-DBR 73 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: API Gravity Bg Bo CCE DV GLR GaR La n OBM P Pb PV Pi R Rs T V Vr STL STO %,w/w Z BP S-213A Field: Sand: Job#: Prudhoe Bay Sc~lumbePlep 200400350 Appendix A: Nomenclature and Definitions American Petroleum Institute gravity Gas formation volume factor Oil formation volume factor Constant composition Expansion Differential Vaporization Gas Liquid Ratio Gas Oil Ratio Live Oil Number of moles Oil Based Mud Absolute pressure Bubble point pressure Pressure-Volume Method Initial Reservoir Pressure Universal gas constant Solution gas oil ratio Temperature Volume Relative volume Stock Tank Liquid Stock Tank Oil Weight Percent Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.S. Standing Compressibility in constant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation (Gas deviation factor, Z=1) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. · A positive index indicates scaling tendencies. · A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. WCP Oilphase-DBR 74 Job #: 200400350 I Client: BP Field: Prudhoe Bay Schlumb8rl8r I Well: S-213A Sand: Installation: Job #: 200400350 I Appendix B: Molecular Weights and Densities Used Components MW Density (glee) I CO2 44.01 0.827 H2S 34.08 0.993 N2 28. 013 0.808 C1 16.043 0.300 I C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 I N-C4 58.124 0.586 I-C5 72.151 0.625 N-C5 72.151 0.631 I C6 84 0.660 MCYC-C5 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0781 I C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 I C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 I O-XYLENE 106.17 0.884 C9 121 0.768 C10 134 0.782 I C11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 I C15 206 0.836 C16 222 0.843 C17 237 0.851 I C18 251 0.856 C19 263 0.861 C20 275 0.866 I C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0885 I C25 337 0.888 C26 349 0.892 C27 360 0.896 I C28 372 0.899 C29 382 0.902 I I WCP Oilphase-DBR 75 Job #: 200400350 I I I I I I I I I I I I I I I I I I I I Client: Well: Installation: BP S-213A Field: Sand: Job#: Prudhoe Bay Schlumberler 200400350 Appendix C: EQUIPMENT Fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below! provides the full fluid compositional analysis, GOR, density at sampling P& T corrected to standard conditions. The JEFRI gasometer consists of a motor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psia) and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography (GC). Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FID!. In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from C, to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas (helium) through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention" times. The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns. The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane) while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C'2+' along with the associated naphthenes and aromatics that are lumped into the C6+ fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCD! while the C5+ components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allowing for the correct separation and analysis of the injected gas. fluid Volumetric (PVT) and Viscosdy Equipment wcP Oilphase-DBR 76 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: BP Field: Well: S-213A Sand: Installation: Job #: 200400350 The preliminary saturation pressure. constant composition expansion (CCE). differential vaporization (DV). multi-stage separation tests (MSST) are measured using a pressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume. visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer. mounted on the bottom end cap of the PVT cell. allow quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. Prudhoe Bay Scblumberger A variable volume JEFRI displacement pump controls the volume. and hence. the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket. which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled. forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTD) and displayed on a digital indicator with an accuracy of 0.2°F. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 % of full sca Ie. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa) and 360°F (182°C). The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with a high-resolution video camera that minimizes parallax in readings and uses a high- resolution encoder producing both linear and volumetric readings. The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides, which allows measurement of extremely small volumes of liquid (0.005 cc) corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer, which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. WCP Oilphase-DBR 77 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: BP Field: Well: S-213A Sand: Installation: Job #: 200400350 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSP) due to changes in the temperature, pressure and/or composition. These fiber optic probes are mounted across the windows of the visual cell. The principle behind the measurement is based on the transmittance of a laser light in the near infra red (NIR) wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. In this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation, isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables (i.e., temperature, pressure, solvent volume, time and transmitted light power level) are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system (LSS). Prudhoe Bay Schlumberger High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10,000 psia. The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. WCP Oilphase-DBR 78 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: BP S-213A Field: Sand: Job#: Prudhoe Bay Schlumb8Pgep 200400350 Appendix D: PROCEDURE Fluids Preparation and ValIdation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, a sub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, a pressure-volume (P-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoint pressure and relative oil volumes over the entire pressure range. Differential Vaporization Procedure Subsequent to the completion of the CCE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (OV) experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a OV test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the OV test. · The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the DV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) · The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. Multi-Stage Separation Test WCP Oilphase-DBR 79 Job #: 200400350 I I I I I I I I I I I I I I I I I I I Client: BP Field: Well: S-213A Sand: Installation: Job #: 200400350 Subsequent to the completion of the DV experiment another sub-sample of the test fluid is charged to the PVT apparatus ðnd the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a separation test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. Prudhoe Bay Schlumbepgep . · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. A portion of the live reservoir fluid used in the DV test is then transferred into a high-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank 0/1 (STD) Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. Asphaltene, Wax and Sulfur Content Measurements Asphaltene content of stock-tank oil samples is conducted using the IP-143 (French Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure. . All other STO analysis were measured according to industrial standards. WCP Oilphase-DBR 80 Job #: 200400350 I I I I I I I I I I I I I I I I Client: Well: Installation: BP S-213A Field: Sand: Job #: Prudhoe Bay Schlumberger 200400350 SAR(P)A Analysis A spinning band distillation was carried out on the original sample to establish two fractions. The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes). This method dissolves the fraction in an equal weight of toluene, then 40 volumes of pentane were added to precipitate the insoluble portion of the sample. The precipitate was filtered, dried and weighed. The solvent was removed from the soluble portion of the sample, which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates, aromatics and resins (polars) fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High- Temperature High Pressure FIltration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. WCP Oilphase-DBR 81 Job #: 200400350